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Home My WebLink About20150747.tiff ENVIRONMENTAL E fl© November 5, 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 C5 Injection Facility SWSW Section 29, T2N, R64W Hudson, Weld County, Colorado CGRS Project: 1-12462-14686ac Dear Mr. Valencia: Please find the enclosed SPCC Plan that CGRS, Inc. (CGRS) prepared for the above referenced NGL Water Solutions DJ, LLC (NGL) C5 injection facility in Hudson, Colorado. This plan has been certified by a P.E., but its purpose is to provide you with the needed documentation to present to the appropriate personnel for building permits and public hearings. Once the C5 facility is constructed, CGRS will perform a formal site SPCC inspection based on the completed facility's layout and current equipment. The final plan will also be certified by a P.E. 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. Travis M. Domingo Project Manager/Scientist Enclosures SPCC Plan 1301 Academy Court Fort Collins, CO 80524 T 800-288-2657 F 970-493-7986 www.cgrs.com SPILL PREVENTION , CONTROL , AND COUNTERMEASURE PLAN IDI November 5 , 2014 111 NGL Water Solutions DJ , LLC C5 Injection Facility ID Weld County, Colorado II CGRS Project Number: 1 - 12462- 14686ac Prepared for: IND M3 Construction , LLC 2681 W 120th Avenue , Suite 250 Di Westminster, Colorado 80234 Ili Ili Ili Ili Prepared by: ip. CG "We solve problems " CGRS, Inc. 1301 Academy Court Fort Collins , CO 80524 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)] 4 2.9 Discharge Controls [ 1 12.7(a)(3)(iii) 5 2. 10 Countermeasures: Discovery/Response/Cleanup [ 112.7(a)(3)(iv)] 6 2. 11 Disposal [ 112.7(a)(3)(v)] 6 2. 12 Notification Phone List [ 112.7(a)(3)(vi)] 7 2. 13 Discharge Notification Form [ 112.7(a)(4)] 7 2. 14 Discharge Procedures [ 112.7(a)(5)] 8 2. 15 Discharge Prediction [ 112.7(b)] 10 2. 16 Secondary Containment for Loading/Unloading Areas Other Than Rack [ 112.7(c)] 10 2. 17 Statement of Impracticability [ 112.7(d)] 11 3.0 INSPECTIONS, TESTS AND RECORDS 11 3. 1 Inspections and Record-Keeping [ 112.7(e)] 11 4.0 PERSONNEL TRAINING 11 4. 1 Personnel Instruction [ 112.7(0( 1 )] 11 4.2 Designated Individual for Spill Prevention [ 112.7(0(2)] 12 4.3 Spill Prevention Briefings [ 112.7(0(3)] 12 5.0 SECURITY [ 112.7(g)] 12 5. 1 Securing and Controlling Access 12 5.2 Securing Master Flow/Drain Valves 12 5.3 Preventing Unauthorized Access to Starter Controls 12 5.4 Securing Loading/Unloading Connections 12 5.5 Security Lighting 12 6.0 TANK TRUCK LOADING AND UNLOADING 13 6. 1 Secondaiy Containment for Loading/Unloading Areas Including Racks [ 112.7(h)( 1 )] 13 6.2 Warning Barrier Systems [ 112.7(h)(2)] 13 6.3 Bottom Drains of Vehicles Examined [ 112.7(h)(3)] 13 7.0 OTHER GENERAL REQUIREMENTS 13 7. 1 Brittle Fracture/Other Failure Evaluation — Field Constructed Aboveground Containers [112.7(i)] 13 7.2 Conformance with Stricter State Rules [112.7(j)] 13 7.3 Oil-filled Operational Equipment [112.7(k)] 13 8.0 FACILITY DRAINAGE 13 8. 1 Drainage from Diked Areas [112.8(b)(1)] 13 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)] 14 8.5 Backup Pump for Lift Station and Transfer Systems [112.8(b)(5)] 14 9.0 BULK STORAGE TANKS 14 9. 1 Containers Compatible with Materials Stored [112.8(c)(1)] 14 9.2 Secondary Containment [ 112.8(c)(2)] 14 9.3 Rainwater Drainage Procedure [112.8(c)(3)] 15 9.4 Buried Metal Tanks Corrosion Protection [112.8(c)(4)] 15 9.5 Partially Buried Tanks Protected Against Corrosion [112.8(c)(5)] 15 9.6 Integrity Testing [112.8(c)(6)] 15 9.7 Internal Coils [ 112.8(c)(7)] 16 9.8 Engineered to Avoid Discharges [ 112.8(c)(8)] 16 9.9 Plant Effluent Discharges to Navigable Water [112.8(c)(9)] 16 9. 10 Oil Leaks Promptly Corrected [112.8(c)(10)] 16 9. 11 Mobile or Portable Oil Storage Tanks [ 112.8(c)(11)] 17 10.0 FACILITY TRANSFER OPERATIONS 17 10. 1 General 17 10.2 Buried Pipe Installations [112.8(d)(1)] 17 10.3 Terminal Pipe Connections Capped or Blank Flanged [ 112.8(d)(2)] 17 10.4 Aboveground Pipe Supports [ 112.8(d)(3)] 17 10.5 Testing and Inspection of Aboveground Pipes and Valves [ 112.8(d)(4)] 17 10.6 Warning for Trucks of Pipes [112.8(d)(5)] 18 11 .0 SUBSTANTIAL HARM [ 112.20(e)] 18 FIGURES FIGURE 1 : Site Location Map FIGURE 2: Site Layout Map FIGURE 2B: Site Conditions Map PROCESS FLOW CHART 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 ✓ CG ' Spill Prevention Control and Countermeasure Plan NGL C5 Injection Facility November 5, 2014 Ame "We solve problems' 1 . 0 PLAN CERTIFICATION 1 . 1 Certifying Engineer's Statement [112. 3(d)] : The undersigned Registered Professional Engineer is familiar with the requirements of the Code of Federal Regulations, Title 40, Part 112 (40 CFR Part 112), has examined the proposed plans of the facility, and he or his agent will examine the facility upon completion of construction. 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: }3 a0 jeer 3 D1/40k4 . rannan Davis, P.E. Colorado State Registration No: 44268 �a%%%‘ ‘‘\\ Pp$ OO �... 4/6)\‘‘.I & •••�$AN ea, I SQ b 9i o � /i :m • • 442 . = :/ • /. �. t� tp •` i 400 k‘ /ON At.E�..;_ 1 .2 Management Approval Statement [112.7]: 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 C5 injection facility and will provide the manpower, equipment, and materials required to expeditiously control and remove any quantity of oil discharged that may be harmful. Date: Mr. Josh Patterson Certifying Official NGL Water Solutions DJ, LLC 1 Spill Prevention Control and Countermeasure Plan CG NGL C5 Injection Facility Di November 5, 2014 "We solve problems" 2 . 0 GENERAL 2. 1 SPCC Plan Description [112.7(a)( 1 )] The following SPCC Plan has been developed as part of a comprehensive plan to minimize the potential for oil discharges at the NGL Water Solutions DJ, LLC (NGL) C5 injection facility located in Hudson, 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 [112.3(e)] The NGL C5 injection 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 31 miles southwest from the NGL C5 injection facility location. The plan is available for inspection, at either the main office or the C5 facility, by regulatory officials at all times. 2 .3 Amendment and Review Procedures [112 . 5] 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. 2 Spill Prevention Control and Countermeasure Plan CG NGL C5 Injection Facility November 5, 2014 "We solve problems" Technical Amendments L 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). LI 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. 2 .4 Facilities Not Yet Operational [112.7] The NGL C5 injection facility described in the SPCC Plan is not operational at the time this SPCC plan was prepared and is expected to be fully operational in June 2015. This preliminary plan satisfies the requirements to obtain the necessary permits to construct the site. Upon completion of the facility, this SPCC plan will be amended to accurately describe facility operations based on the results of the formal SPCC inspection of the facility. Planned spill prevention improvements and procedures will be established within six months from the date of the final SPCC plan. 2 .5 Deviations from Requirements [112.7(a)(2)] The NGL C5 injection facility does not include any deviations from the SPCC requirements. 2.6 Facility Description [112.7(a)(3)] NGL owns and operates the NGL C5 injection facility which is an onshore oilfield water storage and Class II injection facility. Oilfield production water with oil concentrations ranging from 1 .5% to 3% oil within the production water is transported to the site by tanker trucks that vary in capacity up to approximately 9,240 gallons (220 BBL). Production water is offloaded and pumped into the facility for treatment. The facility employs various treatments to separate solids, oil, and water. Recovered oil is sold and removed from the site via tanker truck and produced water is re-injected into the subsurface. All transfer operations and bulk storage above ground storage tanks (ASTs) are located within adequately sized secondary containment. The physical facility layout including the storage capacity and storage material of SPCC regulated equipment is shown on Figure 2B, the Site Conditions Map. 3 Spill Prevention Control and Countermeasure Plan CG NGL C5 Injection Facility November 5, 2014 "We solve problems" Overall, the facility consists of a concrete loading/unloading pad, 20 process and storage ASTs, pump house, and one injection well. The facility contains a 2,520-gallon (60 BBL) sump which collects runoff from the offloading area and any precipitation or spills are pumped into the treatment ASTs when necessary (See Process Flow Chart). The facility is located in the Southwest 'A of the Southwest 'A of Section 29, Township 2 North, Range 64 West, in Weld County, Colorado, approximately 1,500 feet south of Interstate 76 along Weld County Road 51 . The facility is surrounded by native grasses and agricultural land. The regional topography is relatively level with drainage to the west and southwest. Surficial runoff within the concrete loading/unloading area will be captured within the trench drain which drains to the unloading sump. All other site runoff is generally sheet flow to the west and southwest where the water should eventually infiltrate into surficial soils. The nearest significant water body is De Remer Lakes, located approximately 1 mile to the south and east of the facility. Site location and area topographic and surface water features are depicted on Figure 1 (topographic map). General site layout and site conditions are shown on Figures 2 and 2B, respectively. 2.7 Facility Storage [112.7(a)(3)(i )] The following table describes ASTs associated with produced water treatment and recovered petroleum storage at this facility: Capacity 'Tank Dimentions (Dia. Tank ID# BBI.s Tank Process (ft)/Height (ft) Construction Material (gallons) T1 & T12 700 De-Sanding Tanks 12/40 Fiberglass reinforced plastic (29,400) (unloading tank) 1,000 Fiberglass reinforced plastic AST T2 & T11 (42,000) Oil Skim Tanks 15.5/30 T3-T10 840 Water 15.5/25 Fiberglass reinforced plastic (35,280) Equalization Cl & C2 1,000 Clean Tank 15.5/3() Fiberglass reinforced plastic (42,000) 400 O1 - O3 (16,800) Oil Storage 12/20 Vertical, ingle-wall, steel, shop fabricated 400 OS (16,800) Sale Oil Storage 12/20 Vertical, ingle-wall, steel, shop fabricated 400 O-Slop 16 800 Waste Oil Storage 12/20 Vertical, ingle-wall, steel, shop fabricated ( ) 400 OH (16,800) Heat Oil Storage 12/20 Vertical, ingle-wall, steel, shop fabricated Total 13,720 (576,240) 2.8 Discharge Prevention Measures [112 . 7 (a )(3)(ii)] NGL ensures that any releases due to spilling or overfilling do not occur by: 1 . Only accepting disposal water when there is adequate capacity in the tanks to receive product. 4 Spill Prevention Control and Countermeasure Plan CG NGL C5 Injection Facility 414 November 5, 2014 "We solve problems" 2. Visual monitoring of the transfer operation between ASTs, with strict attention being paid to the volume received in accordance with available tank capacity. 3. Manual tank gauging and sight confirmation of tank liquid levels are performed approximately every two hours with additional gauging as needed. 4. 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. 5. Electronic gauges are utilized that automatically shut down the pump transfer when approximately 90% of tank volume capacity is reached. Any water spilled within the pump house during pump maintenance or regular pump operation flows to a floor drain which drains into the 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 ❑ All hatches are closed tightly ❑ Internal safety valves are closed 2.9 Discharge Controls [112.7(a)(3)(iii)] Loading and unloading operations, all ASTs and storage containers, and all associated above-ground piping and equipment are located within diked secondary containment areas which will contain and control any potential discharges from the tanks, equipment, and transport trucks. Any spills occurring within the pump house will be contained via the storm drain leading to the sump. 5 Spill Prevention Control and Countermeasure Plan CG NGL C5 Injection Facility November 5, 2014 "We solve problems" 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, and a 3-inch PVC pipe will be installed under the offload sump to monitor any leaks in the containment area. This will be monitored according to the facility's ground water monitoring plan. if applicable, NGL instructs oil handling personnel to assure that all 55-gallon oil drums are stored properly and within containment areas 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)] NGL employees and contractors are aware of the need to immediately report all spills and releases of oil products to Mr. Josh Patterson, the primary contact (See Appendix D). 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 Hudson Fire Protection District will be utilized 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, at the tank farm and the pump house, that are immediately available on-site to respond to spills and begin immediate cleanup measures. Heavy equipment, including excavation vehicles and equipment, are on-call in the area provided by Mundt Oilfield Services. Pumps and vacuum tanker trucks are also on-call 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 employed, if needed. Discovery, response, and cleanup activities are described in more detail in the following sections. 2 . 11 Disposal [112 .7(a)(3)(v)] 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 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 6 Spill Prevention Control and Countermeasure Plan CG NGL C5 Injection Facility hi November 5, 2014 'We solve problems" 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)] 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 outside of a secondary containment area 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: Hudson Fire Protection District Hudson, Colorado 911 (24-Hour) (970) 454-0681 (Main Number) 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 [112.7(a)(4)] 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 7 Spill Prevention Control and Countermeasure Plan CG NGL C5 Injection Facility November 5, 2014 'We solve problems" ❑ 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 17 Maximum storage or handling capacity of the facility and normal daily throughput ❑ Corrective action and countermeasures taken, description of equipment repairs and replacements O Description of the facility, including maps, flow diagrams, and topographic maps, as necessary 11 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 O Any other information as the Regional Administrator may reasonably require pertinent to the Plan or discharge 2. 14 Discharge Procedures [112.7(a)(5)] After identifying and locating a spill, the necessity for and feasibility of effective containment will be assessed. Containment will be initiated as soon as possible to prevent undue spreading of released product. The first action will be the elimination of any additional spillage if safely possible. 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 C5 facility indicates a low potential for release because all transfer operations and oil-containing vessels are located within full secondary containment. Additionally, several of the manifolded ASTs are equipped with high level alarms to reduce the risk of overfilling. The C5 facility 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. 8 Spill Prevention Control and Countermeasure Plan CG ' NGL C5 Injection Facility 414 November 5, 2014 Ile "We solve problems" Volume Estimated Direction of Secondary Source Type of Failure (gallons) Flow Rate Flow, Containment Outward De-sanding Tanks Concrete secondary (T1 & T12) Rupture 33,600 Gradual to within containment with instantaneous containment to south collection sump Outward Concrete secondary Oil Skim Tanks Rupture 25 200 Gradual to within containment with (T2 & T11) instantaneous containment to south collection sump Water Outward Equilization ASTs within Concrete secondary (filtered Rupture 21 ,000 Gradual to containment containment with instantaneous production water) to south collection sump (T3-T10) Clean Water Outward (water and minor Gradual to within Concrete secondary Rupture 42,000 containment with oil mixture) instantaneous containment (C 1-C2) to south collection sump Volume Estimated Direction of Secondary Source Type of Failure (gallons) Flow Rate Flow Containment Outward Oil StorageTanks Concrete secondary (oil) Rupture 12 600 Gradual to within containment with (O1-O3) instantaneous containment collection sump to south Outward Oil Slop Tank Concrete secondary (water/oil) Rupture 16 800 Gradual to within containment with (O-slop) instantaneous containment collection sump to south Outward Oil Heat Tank Concrete secondary (oil) Rupture 16,800 Gradual to within containment with (OH) instantaneous containment collection sump to south Outward Sale Oil Tanks Concrete secondary (oil) Rupture 16 800 Gradual to within containment with (OS) instantaneous containment collection sump to 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, East towards AST concrete Loading from oil connection failure or 1 to 50 50-100 gal/min containment tank load out overfill drain containment Active secondary 55-Gallon drums Rupture 1 to 55 Gradual to Radial containment (if applicable) instantaneous across floor materials, spill response absorbents 9 Spill Prevention Control and Countermeasure Plan CG NGL C5 Injection Facility November 5, 2014 'We solve problems" * 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 time frame of 30 seconds. In case of a spill or release outside of the containment areas, active controls may be needed along the leading edge of the spill to prevent spreading when necessary. 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 [112.7(b)] A review of planned operations at the C5 Facility indicates a low potential for a spill or a release outside of secondary containment. There have been no reported spills of petroleum products at the facility that have qualified as "spill events" under the federal definition as the facility is yet to be constructed. 2. 16 Secondary Containment for Loading/Unloading Areas Other Than Rack [112.7(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 unlikely 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, on-site 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. 10 Spill Prevention Control and Countermeasure Plan CG NGL C5 Injection Facility DiIs November 5, 2014 'We solve problems" 2. 17 Statement of Impracticability [112.7(d)] Not applicable as secondary containment is provided for all oil storage containers at the facility. 3 . 0 INSPECTIONS , TESTS AND RECORDS 3. 1 Inspections and Record-Keeping [( 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, monthly and annually to ensure that there has been no failure of the tanks or associated equipment and to assess the general operational intregity of facility equipment. Periodic certified inspections are also performed on the tanks, piping, and transfer equipment. Completed storage tank inspection reports will be 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 will be kept on file with the SPCC Plan for a minimum period of three years. Inspection and recording forms are provided in Appendix F. 4 . 0 PERSONNEL TRAINING 4. 1 Personnel Instruction [112.7(f)( 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 be 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. 11 Spill Prevention Control and Countermeasure Plan CG NGL C5 Injection Facility November 5, 2014 'We solve problems" 4.2 Designated Individual for Spill Prevention [112.7(f)(2)] 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 [112.7(f)(3)] 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. 5 . 0 SECURITY [ 112 . 7(g )] 5. 1 Securing and Controlling Access The NGL CS 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 oil 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. 12 Spill Prevention Control and Countermeasure Plan CG NGL C5 Injection Facility 4 Its November 5, 2014 'We solve problems" 6 . 0 TANK TRUCK LOADING/UNLOADING 6. 1 Secondary Containment for Loading/Unloading Areas Including Racks [112.7(h )( 1 )] The ASTs at the facility do not include loading/unloading racks. 6. 2 Warning/Barrier Systems [112 .7(h )(2)] Signs warning drivers to disconnect transfer lines before departure are posted in offloading/loading areas. 6. 3 Bottom Drains of Vehicles Examined [112.7(h )(3)] NGL assures that prior to filling and departure of any tanker 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 [112.7(i)] The NGL C5 facility does not include field-constructed ASTs. 7.2 Conformance with Stricter State Rules [112.7(j)] No stricter State discharge prevention and containment procedures are applicable to this facility. 7.3 Oil-filled Operational Equipment [112.7(k)] The C5 facility has one oil-filled electrical transformer, which is owned and operated by Xcel Energy. Xcel is responsible for all aspects of internal access, operation, and maintenance of the transformer and it is not included as qualified oil filled operational equipment in this SPCC. 8 . 0 FACILI TY DRAINAGE 8. 1 Drainage from Diked Areas [112.8(b)( 1 )] The C5 secondary containment area is constructed entirely of concrete, with drains routed to the sump. All fluids untentionally discharge outside of the ASTs and/or piping within the containment areas are routed to the sump, which is pumped back into the treatment system. The trench drain located on the unloading/loading pad also drains to the main sump. 13 Spill Prevention Control and Countermeasure Plan CG NGL C5 Injection Facility November 5, 2014 'We solve problems" 8.2 Dike Drainage Valves — Manual , Open/Closed Designed [112.8(b)(2)] There is no dike drainage valves associated with the AST or loading/unloading secondary containment areas. The secondary containment areas route all water to the sump. 8.3 Drainage System for Undiked Areas [112.8(b)(3)] 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 [112 .8(b)(4)] In the unlikely event of a discharge outside secondary containment areas, oil absorbent materials maintained at the facility will be used to help 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 [112.8(b)(5)] NGL does not operate drainage lift stations at the C5 facility. 9 . 0 BULK STORAGE TANKS 9. 1 Containers Compatible with Materials Stored [112 .8(c)( 1 )] The ASTs and any portable containers used for storage of water and petroleum products at the NGL C5 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 [112.8(c)(2)] All production water and oil ASTs are contained within the main concrete secondary containment area. The containment area is drained by an underdrain system which will convey precipitation and any released fluids to the sump. The containment area is designed to hold the tank with the largest capacity (42,000 gallons) plus freeboard allowance for precipitation. The total calculated capacity of the containment area is 153,061 gallons (3,644 BBL). 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 48,752 gallons (1,645 BBL). The unloading pad at the CS facility drains into the sump located adjacent the secondary containment. The unloading pad is designed with adequate capacity to hold the volume of the largest tank of tanker truck (9,240 gallons or 220 BBL) plus freeboard allowance for precipitation. The total calculated capacity of the unloading containment area is 63,803 gallons (1 ,518 BBL). Considering the freeboard allowance for a predicted 24-hour, 100- 14 Spill Prevention Control and Countermeasure Plan CG NGL C5 Injection Facility Di November 5, 2014 "We solve problems" year storm event for the area, the adjusted available volume in the offload area plus the unloading sump is approximately 19,164 gallons (456 BBL). The secondary containment systems at the NGL C5 facility are designed to be impervious to contain spills from the largest tank without loss of oil until cleanup measures are implemented. Excess precipitation is routinely removed from the secondary containment sump to maintain adequate spill retention volume for the tanks. Secondary containment volume calculations are presented in Appendix H. 9.3 Rainwater Drainage Procedure [112 .8(c)(3)] Precipitation that accumulates within the diked areas drains to the containment area sump, then pumped into the production water holding tanks. 9.4 Buried Metal Tanks Corrosion Protection [112.8(c)(4)] The facility does not currently operate buried tanks. 9.5 Partially Buried Tanks Protected Against Corrosion [112.8(c)(5)] The facility does not operate partially buried tanks. 9.6 Integrity Testing [112.8(c)(6)] NGL assures that all ASTs are maintained in good condition. 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 Stn 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 from the presence of spills or leaks, which is removed if present. The secondary containment sump is checked to assure it is 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. 0 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 15 Spill Prevention Control and Countermeasure Plan CG NGL C5 Injection Facility November 5, 2014 'We solve problems" 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 will 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 performed. 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 [112.8(c)(7)] internal coils are present in the heated oil tank (OH), and are inspected on a monthly basis to detect leaks or malfunction of the heating compound. 9.8 Engineered to Avoid Discharges [112.8(c)(8)] 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. 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. All tanks are equipped with overfill pump shut off sensors, which automatically shut down the pumps once tanks reach approximately 90% available capacity. All storage, treatment, and transfer operations are conducted within adequately) sized secondary containment. 9.9 Plant Effluent Discharges into Navigable Water [112.8(c)(9)] The facility does not have plant effluent discharges to navigable waters. 9. 10 Oil Leaks Promptly Corrected [112 .8(c)( 10)] Any oil leaks are promptly corrected, reported to management, and abated. 16 Spill Prevention Control and Countermeasure Plan CG NGL C5 Injection Facility November 5, 2014 'We solve problems" 9. 11 Mobile or Portable Oil Storage Tanks [112.8(c)(11 )] There are no portable oil storage containers at the facility. Should any portable container containing over 55-gallons comes on site, they will be, added to the SPCC plan, stored within a containment area, and included in routine inspections, etc. 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 ❑ All valves and above ground piping are located within secondary containment ❑ 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 )] Most facility piping is aboveground and readily visible for inspection. Piping related to the pump house including piping connecting the clean water AST to the pump house and piping from the pump house 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)] 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)] 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)] Valves and piping are examined monthly to assess the condition of the transfer equipment. The dispensing 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. 17 Spill Prevention Control and Countermeasure Plan CG NGL C5 Injection Facility hs November 5, 2014 'We solve problems" 10.6 Warning for Trucks of Pipes [112.8(d)(5)] No aboveground piping is exposed outside of the secondary containment, or exposed to vehicular traffic. The unloading pumps 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 [ 112 . 20(e)] 40 CFR 112.20 (0(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. 18 FIGURES _ '� � 1�8 49�pI 493 \‘‘,.: . 4Q69 �.4�ei�E � •, \, _ ^ ? ..,-- A, \ \ . < 4 \ r • \ -20 a� 1 0 'Ws Q, 21\ §( 4::\ , 11 fr " a at \ \ NH. 6\ .• 1 \..e.. '•\ \\ . '. 2 1----- -- ------‘ % • %. - --- a )1 \ _.)_) *t: 4) . * :\s, t. , i ( \ . (----1- ., () -. ilikb, `-ak, 1 \ ,19 0 _______,./. 1 ,, .,, 1 .,._.. K\1/4,.. VI._ -1/4, ' ..fr.--0 % --------..N.N\ . • i f • 745 ' 937 • fit 4 / \-:: ',f r vim. Cc......./..\\ .-1 ic f‘ + ‘ -' • 98 \Attel".* t BM Cr4. i" in IL a 1 * . N Fhor.4fl4 '� �_V R4ihG r ----,P. �9. 4VYt?I w Vma Nirt, ' �' -r--- . ref Il fla Q ISN-- r. .- r . SITE ++ J �� • �' LOCATION s , r 0l C� p , 4 9,23 • a 0 -"a\t". V � „ S(/f • JIZI 9 c. . ic... 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Ft , it iii .. - /y / rj Inas �--� FIGURE 1 ■ SITE LOCATION MAP MW CONSTRUCTION, LLC C5 NGL WATER SOLUTIONS COLORADO I SW 1/4, SW 1/4, Sec. 29, T2N, R64W HUDSON, COLORADO I'1 PROJECT: DRAFT: C/� ■ 0 1000 2000 1-12462-14686aa MS V ENVIRONMENTAL ��.ai CONSTRUCTION MIQUADRANGLE LOCATION DATE: REVIEW: O W COMPLIANCE SCALE IN FEET 11/3/2014 m CROPLAND IS G one f— ore CROPLAND(---_ i obE X16 �_ ohE � OhE G ' (Pe -40-- G pre— ' G phE G sr G OhE IRRIGATION DITCH-� G Owe ---------------/„...---------G ' OhS' G /J JIM CREEK #1-29 4 Ord WELLHEAD/ors/ - ,I ND\ 0 a0 CROPLAND / CO ) i�ER,ES ors` -- V 6^ --, --, I — v / I II 1 1 CROPLAND Q I 11 1 1 -� phE I I I I I o \41/4 L--JL--J L__ - phE 0 / _ OhE O 1 / -.411----- _------ C OhE -I BAUMGARTNER #14-29 -< e-------- WELLHEAD 70 D I i f C I cm o IRRIGATION IRRIGATION DITCH- COLLECTION ABANDONED PROPERTY-\ DITCH PROPERTY BOUNDARY - - - - - - - - 24" CULVERT I SOIL I hE 0 OhE 0 0 ohE OhE- - / o = =1 — OhE 0 OhE — OhE O OhE cr OhE 00 OPf_ COUNTY ROAD 16 1 ._ NEW WELL PAD - -WETLAND —(UNDER CONSTRUCTION) LEGEND FIGURE 2 0 UTILITY POLE - FO FIBER OPTIC LINE (BURIED) SITE CONDITIONS MAP M3 CONSTRUCTION, LLC ab RETENTION POND — OhE OVERHEAD ELECTRIC LINE C5 NGL WATER SOLUTIONS • WELL HEAD - O - GAS LINE SW 1/4, SW 1/4, Sec. 29, T2N, R64W HUDSON, COLORADO SURFICIAL FLOW DIRECTION ------- PROPERTY BOUNDARY (APPROXIMATE) PROJECT: DRAFT: FENCE o aoo zoo 300 400 500 1-12462-14686aa MSB CG ENVIRONMENTAL CONSTRUCTION DATE: REVIEW: i ill! COMPLIANCE IIIIIIIIII RAILROAD .;.; .. SCALE IN FEET 11/4/2014 '"� , TANK BATTERY I / -ACCESS ROAD- SECONDARY CONTAINMENT- "� FUTURE TANK FARM-\..Nr O-SLOP ci c2 os r 1 Ts (r 1 @ PUMP S ® 6HOUSE T9 @ @ r 1.O O1 T3 @ O O1 @ 0 Q S O L J L- � J L 0 re /7 - y. FUTURE I- RECYCLE Z BUILDINGS O -ACCESS ROAD- __----) V AN. o '''''`• W PAD MAP SIZE TANK ID (BBLS) ID T1 700 DESANDING AST T2 1000 OIL SKIM AST T3 840 WATER EQUALIZATION AST T4 840 WATER EQUALIZATION AST T5 840 WATER EQUALIZATION AST 1 T6 840 WATER EQUALIZATION AST T7 840 WATER EQUALIZATION AST IRRIGATION T8 840 WATER EQUALIZATION AST COLLECTION T9 840 WATER EQUALIZATION AST DITCH T10 840 WATER EQUALIZATION AST FIGURE 2B 01 400 OIL AST SITE CONDITIONS MAP 02 400 OIL AST M3 CONSTRUCTION 03 400 OIL AST C5 NGL WATER SOLUTIONS OH 400 OIL HEAT AST SW 1/4, SW 1/4, Sec. 29, T2N, R64W HUDSON, COLORADO 0-SLOP 400 SLOP OIL AST 05 400 SALE OIL AST PROJECT: DRAFT: CG D Cl 1000 CLEAN AST o so loo 1so 1-12462-14686aa MSB ENO �IO CONSTRUCTION P1 DATE: REVIEW: C2 1000 CLEAN AST 4 A COMPLIANCE SCALE IN FEET 11/4/2014 ...- NGL Water Solutions DJ, LLC C5 Injection Facility SWSW, Sec. 29, T2N, R64W Facility Process Flow Chart Production Water Unloading Pad Water is unloaded from tanker trucks into Desanding Tanks Sediment Oil Skim Tanks Initial Crude Oil Separation Recovered Crude Oil Production Water Process Tanks Process Water Treatment to Recover Crude Oil Filtration Crude Oil Storage Tanks (4 x 500 BBL) Routed to Pumphouse to filter Production Storage Tanks for Oil Water for the removal of left over crude (< 1.6 ) and sediment Clean Water Tanks Crude Loadout Storage of Clean Water Injection Notes: * Conservative 1.6 based on mass balance of silimar facilities and layouts Crude oil Stream Production Water & Crude Oil Stream a Sediment Stream Clean Water APPENDIX A SPCC REVIEW LOG SPILL PREVENTION CONTROL AND COUNTERMEASURE PLAN REVIEW LOG FOR TECHNICAL AMENDMENTS: NGL Water Solutions DJ, LLC C5 Saltwater Injection 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 Water Solutions DJ, LLC, C5 Saltwater Injection Facility, Hudson, 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, C5 Saltwater Injection Facility, Hudson, 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 C5 Injection Facility Review and Amendment Log Review/Amend Signature Amend Plan Description of Review Affected Page(s) Date (will/will not) Amendment 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, C5 Injection Facility AST # Street SWSW, Section 29, T2N, R64W Product in tank _ address City Hudson, 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. f) 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 Department of Transportation 49 CFR Page 2 leakage 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. 1) 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 13 - 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. f) 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 single driven motor vehicle or in any single 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 LC (130 LF) — either on a thermostatically controlled heater or on a heater without thermostatic control when the outside or ambient temperature is 16 CC (61 EF) 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 (1)(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 LU (129 lam'). 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 (1)(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 MI-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, C5 Injection Facility;SWSW Section 29, T2N, R64W Hudson, 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 Office 970-356-5560 office cell phone Local Emergency Contacts Are: ❑ Hudson Fire Protection District — 911 u 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, C5 Injection Facility;SWSW Section 29, T2N, R64W Hudson, 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. C 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. I_I 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 Apply) Dike/Berm: Oil-Water Separator: Other: Did Oil Reach a Waterway: Yes / No Quantity Released to Waterway: Waterway Name: 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, LLC, C5 Injection Facility SWSW, Sec. 29, T2N, Inspection Date: R64W 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. obstructions? No —Yes (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 Visible leaks on aboveground pipes, If"yes," describe, record corrective action taken and date done. 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 ft"no." describe, record corrective action taken and date done. with no sign of severe corrosion or No Yes N/A damage 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. No Yes properly sealed — — (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. _No _Yes interstitial space for liquid: Is liquid N/A present?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 operation or that may affect the site No _Yes SPCC plan? Additional Comments: Inspector Name Signature Date ABOVEGROUND STORAGE TANK "ANNUAL" VISUAL INSPECTION FORM Page 1 of 2 Facility Name/Address: NGL Water Solutions DJ, LLC, C5 Injection Facility SWSW, Sec. 29, T2N, Inspection Date: R64W 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 continued —No —Yes N/A service? — (2) Tank Foundation and Supports Evidence of tank settlement or If"yes," describe and record action taken to correct problem and date done. No —Yes 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? Flan ed i e connection bolts If"no," describe and record action taken to correct problem and date done. g pip 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 If"yes," describe and record action taken to correct problem and date done. — N o Yes 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 If"yes," describe and record action taken to correct problem and date done. No Yes 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. No Yes lifts as required? — — (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? No 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 good If"no," describe and record action taken to correct problem and date done. 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, C5 Injection Facility SWSW, Sec. 29, T2N, Inspection Date: R64W 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 and gates/doors operable? No _Yes (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 17 es 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 DI, LLC, C5 Injection Facility FACILITY ADDRESS: SWSW Section 29, T2N, R64W; Hudson, Colorado INSTRUCTOR: SUBJECT: SIGNATURES OFATTENDEES: 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 C5 Water Disposal Facility SWSW Section 29, T2N , R64W Hudson , Colorado CGRS Project # 1 -12462-14686ac 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 Section 1 Section 1 Volume 19,500 cubic feet Enter Height 2 feet (Tank Farm ) Enter Width 65 feet Enter Length 150 feet Section 2 Section 2 Volume 960 cubic feet Enter Length 10 feet (Sump Volume) Enter Width 12 feet Enter Depth 8 feet Total Volume 20,460 cubic feet = 153,061 gallons 4. Base Area of Vertical Tanks (within the containment) Tank Sizes De-Sanding Tanks 452 cubic feet De-Sanding Tanks (T1 - T-12) Enter Diameter 12 feet Enter Height 2 feet Quantity 2 each System Tanks 3,774 cubic feet System Tanks (ASTs T2-T11 ) Enter Diameter 15.5 feet Enter Height 2 feet Quantity 10 each Clean Water Tanks 755 cubic feet Clean Water Tanks (ASTs CLN 1 -2) Enter Diameter 15.5 feet Enter Height 2 feet Quantity 2 each Oil Tanks 1 ,357 cubic feet Oil Tanks (ASTs O1 -O3, OH , OS, OSlop) Enter Diameter 12 feet Enter Height 2 feet Quantity 6 each Total Volume 6,338 cubic feet = 47,416 gallons Above Ground Storage Tanks Secondary Containment Volume Calculations NGL Water Solutions DJ , LLC C5 Water Disposal Facility SWSW Section 29, T2N , R64W Hudson , Colorado CGRS Project # 1 -12462-14686ac 4. Available Diked Area = (Total Diked Area) — (Base Area of Tanks) = 20,460 - 6,338 = 14,122 cubic feet 105,645 gallons 5. Estimated Freeboard Allowance Section 1 Section 1 Volume 3,803 cubic feet Enter Height 0.39 feet Enter Width 65 feet Enter Length 150 feet Section 2 Section 2 Volume 3,803 cubic feet Enter Height 0.39 feet Enter Width 65 feet Enter Length 150 feet Total Freeboard 7,605 cubic feet = 56,893 gallons 6. Adjusted Available Diked Area = (Available Diked Area) — (Recommended Freeboard Allowance) = 14, 122 - 7,605 = 6,517 cubic feet Available Volume in Diked Area = 48,752 gallons Note: Freeboard allowance is based on a historical 24-hour storm event for a 100-year reoccurance interval for the region from the National Oceanic and Atmospheric Administration's (NOAA) Atlas 14, Volume 8, Version 2, Greeley Station (PDS-based point precipitati frequency estimates with 90% confidence intervals (in inches)). Horizontally mounted tanks do not significantly impinge on available Offload Pad Containment & Offload Sump Containment NGL Water Solutions DJ LLC C5 Water Disposal Facility SWSW Sec. 29, T2N , R66W Hudson , Colorado CGRS Project # 1 -12438-14686ac Volume of Largest Truck (cu. ft.) = Tank Volume x 0. 1337cu. ft./gal. conversion factor 9,240 gals. x 0. 1337 cu. ft./gal. = 1235.388 cubic feet 1 . Volume Of Offloading Pad Offlload Approach Offload Approach Enter Height 1 . 17 feet Section 1 Volume 5,616 cubic feet Enter Width 120 feet 42,013 gallons 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 Drain/Trench Enter Height 0.83 feet Section 3 Volume 197.54 cubic feet Enter Width 2 feet 1478 gallons Enter Length 119 feet Sump Sump Enter Height 10 feet Section 4 Volume 960 cubic feet Enter Width 12 feet 7182 gallons Enter Length 8 feet Total Volume 8,529 cubic feet 63,802 gallons 2. Estimated Freeboard Allowance Truck Offload Area Freeboard Offload Approach 3,744 cubic feet Enter Height* 0.39 feet Section 1 Volume 28,009 gallons Enter Width 120 feet Enter Length 80 feet Truck Offload Area Freeboard Offload Departure 1 , 170 cubic feet Enter Height* 0.39 feet Section 2 Volume 8,753 gallons Enter Width 120 feet Enter Length 25 feet Freeboard Drain/Trench 93 cubic feet Drain Section 3 Volume 694 gallons Enter Height 0.39 feet Enter Width 2 feet Enter Length 119 feet Freeboard for Sump 37 cubic feet Sump Section 4 Volume 280 gallons Enter Length 0.39 feet Enter Width 12 feet Enter Depth 8 4. Adjusted Available Diked Area = (Offload Pad Areas, sump, drain) — (Recommended Freeboard Allowance) 7,606 - 5,044 = 2,562 cubic feet Available Volume in Offload Area & Sump = 19, 164 gallons Note: Freeboard allowance is based on a historical 24-hour storm event for a 100-year reoccurance 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, C5 Injection Facility FACILITY ADDRESS: SWSW Section 29, T2N, R64W Hudson, Colorado 1 . 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 D 2. Does the facility have a total oil storage capacity greater than or equal to 1 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 i_I 3. Does the facility have a total oil storage capacity greater than or equal to 1 million gallons and is the facility located at a distance (as calculated using the appropriate formula in Attachment C-III 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 I, II, and HI 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 0 4. Does the facility have a total oil storage capacity greater than or equal to 1 million gallons and is the facility located at a distance (as calculated using the appropriate formula in Attachment C-III or a comparable formula') such that a discharge from the facility would shut down a public drinking water intake2? Yes No _ 5. Does the facility have a total oil storage capacity greater than or equal to 1 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 Li 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) Signature VP Operations Title Date Form 40 CFR 112 Appendix C, Attachment C-II A! ffU/I Water Solutions October 31 , 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: CS 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 C5 Salt Water Disposal Facility (Facility), a new facility, located at SWSW SECTION 29, T2N, R64W, Weld County, CO to request coverage under a GP01 for the oil heating tank, oil tanks, slop oil tank, 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 fugitives. 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. 8207 West 20th Street Suite B, Greeley, CO 80634 O: (970)356-5560 F: (970)356-5563 if rr �Il Water Solutions 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 (jpatterson@highsierraenergy.com). Sincerely, NGL Water Solutio DJ, LLC Jo h Patterson VP of Operations Enclosures Appendix A — Construction Permit Application Appendix B — APCD-1 02 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 8207 West 20th Street Suite B, Greeley, CO 80634 O: (970)356-5560 F: (970)356-5563 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: C5 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 SW 'A SW '' SECTION 29, T2N, R64W 6. Reason for Application: (Check all that apply) ® New or Previously Unreported Source Administrative Permit Amendments ❑ Modification of Existing Source ❑ Transfer of Ownership (Complete Section 9 & 10 below) ❑ Request for Synthetic Minor Permit ❑ Company Name Change (Complete Section 9 below) ❑ Other: ❑ Other: 7. Project Startup Date: 2014 /0 . 31 -- H Sig ture of Legally Autho ed Person of Company 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: Z Copy of preliminary analysis conducted by Division Z 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.cdphe.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 Fonns Form APCD-100 Colorado Department of Public Health and Environment S Air Pollution Control Division * '? ' ra76 i Oil & Gas Industry ColoradoD t of Public Construction Permit Application Completeness Checklist andFnvironnient Ver. September 28, 2009 Company Name: NGL Water Solutions DJ, LLC Source Name: C5 Salt Water Disposal Facility Date: October 2014 Yes No Are you requesting a facility wide permit for multiple emissions points? ►1 U 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 �1 � B Air Pollutant Emission Notice(s) (APENs) & " ■ Application(s) for Construction Permit(s) — APCD Form Series 200 C Emissions Calculations and Supporting Documentation ►� � 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 • 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 �1 � 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: U Send an additional application copy Check box if refined modeling analysis included: IN Send an additional application copy Page 1 of 105 Form APCD-100 Construction Permit Application Completeness Checklist 201410 Form APCD-101 . '•c+ Colorado Department of Public Health and Environment Air Pollution Control Division * '7? fax, P. * 4 f'3/4r. „ j8 Colorado Department of Public Health Company Contact Information Form and Etw nnient Ver. September 10, 2008 Company Name: NGL Water Solutions DJ, LLC Source Name: C5 Salt Water Disposal Facility Permit Lori Marquez, Marquez Compliance Contact': Environmental Services, Inc. Contact2: Josh Patterson 13860 Braun Rd. 8207 West 20th Street, Suite B Address: Street Address: Street Golden CO 80401 Greeley CO 80634 City State Zip City State Zip Phone 303-503-4735 Phone Number: Number: 970-356-5560 Fax Number: Fax Number: 970-356-5563 E-mail: lorikm@aol.com E-mail: jpatterson@highsierraenergy.com Billing Billing Contact: Naomi Lauer Contact: (Permit (Annual Naomi Lauer Fees)3 Fees)4 8207 West 20th Street, Suite B 8207 West 20th Street, Suite B Address: Street 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 970-356-5563 Fax Number: Number: 970-356-5563 E-mail: naomi.lauer@nglep.com E-mail: naomi.lauer@nglep.com Check how would you like to receive your permit fee invoice? Mail: ® E-mail: N 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) a 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. (Reg. 3, Part A, Section VI.C) Page 1 of 1 C5 Form APCD-101 Company Contact Information Colorado Department of Public Ileaith and Environment Form APCD-102 Air Pollution Control Division '.- r. . Facility Wide Emissions Inventory Form '...r.September to.200s Colorado t Company Name: NU Mater Solutions IN.lieof blic Source Name: CS Sall Water Disposal Facility and Environment Source AIRS ID: Cnewh.R.d P.lentbl to Emil Pte) Ce.tnlld P•dMMI is.End IPTE) Cbrri tTPl'1 I HAPs len.'PI Cs kola r1011 HAP.Malt) I AIRS ID Eqvlyents4 Dot TSP ►AMID PM3.5 SOS NO. ('0 VOC 87. Tel ER X7I HCHO Aeetel Acre n.Iles Meth 114-TMP TSP 01110 PA116 sot NO. Co 1'O1.04" 8Z Tel Ee I S71 NCHO Atrial Aire ones Mello 114-TAft LI .. .. .. .. O1 1•• or 14 no - .. .. 2.636 0 _ .. • - .. • .. 9.1 I 15} 62' IS 7)6 •• :.811 0 Sup .a .. .. .. - .. .. 4- 61 1'5 28 468 .. _ ••_ 1, . .. .. -. .. .. .. .. _ 416 ._ .. 16.1 .•.sd Hasep Tod 11.4.018,11 .. .. -. .. .. .. I6 r -e 140 0 61 .. _ . 0 .. .. .- -. -- ,. .. 1.8 1 an Ion n 61 . ndLnl.11s-40+8811 .. .. _ .. .. .. 2.1 '9 ISI 0 51 .. .. .. 65' 0 _ .. .. .. .. - 21 `9 I)1 O Sl _ _ - 0 •. OS Slop I•d T•9111 1.0.811.811 - .. .. - - .. 1.2 44 Ili _ n 1S .. _ .. S•• LI - .. .. - - .. • 1.2 44 II 0 15 .. .. r .. ' 99Sales14Teel II.4001441 - - .. .. .. _ 1.2 44 118 •. )3 .. .. .. /•' 0 .. - .. .. .. .. I.7 44 Si o 35 .. .. .. 0 Do uO l sells 12 x.14•hbll - ., _ _ .. 1.3 49 86 ` )] - -- _ 18' 0 .. .. -. .. .. .. - 1.1 49 66 ): .. _ .. 0 Sand tad u.l Rdmmel T lob C x 10301401 •- • - .. .. II 1 50 18 7 3) .. .. 106 n .. - .. .. - 1.1 50 88 11 - .. 106 F<dueM..oral nlWmf_SvmP .. .• - •. .. .. 1.2 4' BJ 7 31 .. .. .. 1'1 0 .. - • .. .. .. .. 1.: J' 83 II .. .. .. )'1 0 Fern.iled Soan<.Suaet.I- 0.0 0.0 0.• 0.0 0.0 80 11.1 < 701 1.784 5e 1.065 • • 0 0.705 0 0 + 0.0 0.0 0.0 0.0 •.• 0.0 14.1 14 I 706 1.7 50 1.005 0 • 0 4105 0 0 Art,s(Mb•Palish Exempt Sera. I I • I t I I I - • Ares Ont.8,1404.10.e o.0 40 to to 0.0 0.0 ; 0 0 0 0 0 • e 0 0 0 00 0.0 0.0 ate e.• LO ate i 0 0 e 0 0 0 • e 0 o APes Ismael i IntNer•M sect« I arr l poll:oon 1 ink.(a a 840bbt) -- .. ., .. .. .. 00 1 0 1 .. - IS _ n - I .. .. .. IS n nu i 1 n PatSsbo T sale 12 a 10'x•tdd) .. .. .. .- .. - 0.0 I 1 0 - 1 n 0 .. .. .. _ - .. - - ' Il 0 ,. 1.500 p1nue17.A .. .. .. .. .. .. I .. .. .. .. .. .. .. .. .. - .. .. .. o.n I 2 1 0 1 .. .. - .. Iml:nih.MsebUnl 0.0 . 0.0 0.0 6 0.6 0.0 •.• 0.11 A 4 a 2 0 • • 17 0 0 0.0 0.0 e.0 a.6 0.0 0.0 0.1 l $ A 6 I 2 0 • 0 11 0 0 Total Al S.wm•r •.0 I 0.0 I a0 I to 1 •a I to I 14.2 I 301 I L710 I 54 1 1.147 1 0 1 0 1 0 16.131 i 0 1 0 I o.a 1 o.e I 0.• I o.0 I 0.0 I 0.l I 14.1 1 flu 11.7 re i 5o I i..87 1 0 I 1 10 I 6111 Ills I.menue4dlHAPa Suaewr7(T P11- 0,4 0.1 0.0 0.5 0.0 0.0 0.0 3.2 e.0 0.0 Cwdolkd H.V'.5.wt ain't 4 ..4 1 of I 0.0 I 0.5 I to 1 0.0 I as 1 5.2 1 6.0 1 0.0 10161010144 TOL Al HAP%(rev;- 4d Ow dolled Mal.Al HAP.(TPI}- 4.e Feomotes: I. Ibis kn n should be convicted loincloth:both existing sooty:sand all proposed new or no ifioatlons to c Laing alas ion sotuac 1. If IM en06sions somoe is n.w then enter'proposed"under the Pont No.and AIRS ID data column 3. IIAP abbreviations include: BZ Benzene 224-TMP 2.2.4-liinclrylpctanc Tol toluene Aerial Acetaldehyde LB Etlry@cniaio Acre Ae ok'1n X'I +'Acne n-Hex n-ilexone HCHO F'onmldelhvk Meth MctM031 4. 1P1 ' Fxa111Nnsigniftmnl Sources should be included when warranted. Company Magna 10/1912014 Page I of 1 AIR POLLUTANT EMISSION NOTICE (APEN) & Application for Construction Permit — Fugitive Component Leak Emissions Permit Number: [Leave blank unless APCD has already assigned a permit # & AIRS ID] Emission Source AIRS ID: / / Facility Equipment ID: Fugitives [Provide Facility Equipment ID to identify how this equipment is referenced within your organization.] Section 01 — Administrative Information Section 02 — Requested Action (Check applicable request boxes) Company Name: NGL Water Solutions DJ, LLC NAILS, or ® Request for NEW permit or newly reported emission source Source Name: Fugitives SIC Code: O Request MODIFICATION to existing permit (check each box below that applies) Source Location: C5 Salt Water Disposal Facility County: Weld O Change process or equipment O Change company name SW % SW '4 SECTION 29, T2N, R64W Elevation: 4951 Feet O Change permit limit O Transfer of ownership 5 Other Mailing Address: 8207 West 20`" Street, Suite B ZIP Code: O Request to limit HAPs with a Federally enforceable limit on PTE Greeley, CO O Request APEN update only (check the box below that applies) Person To Contact: Josh Patterson Phone Number: 970-356-5560 O Revision to actual calendar year emissions for emission inventory E-mail Address: jpatterson@highsierraenergy.com Fax Number: 970-356-5563 ❑ Update 5-Year APEN term without change to permit limits or previously reported emissions Additional Info. Section 03 — General Information Notes: For existing sources, operation began on: / / For new or reconstructed sources, the projected startup date is: / / 2014 Normal Ilours of Source Operation: 24 hours'day 7 days/week 52 weeks/year Brief description of equipment associated with these components: VOC Fugitives Will this equipment be operated in any NAAQS nonattaintnent area? ® Yes O No ❑ Don't Otto www.cdphe.state.co.us apiattainmaintain.html) know, Section 04 - Regulatory Information Colorado Department of Public Health and Environment Air Pollution Control Division (APCD) Is this equipment subject to NSPS 40 CFR Part 60, Subpart KICK? Don't JPO Yes ® No O know This notice is valid for five (5) years. Submit a revised APEN prior to expiration of five-year term, or when a significant change is made Is this equipment subject to NESHAP 40 CFR Part 63, Subpart HH? O Yes ® No ❑ Don't n (increase production, new equipment, change in fuel type, etc). List any other NSPS or NESHAP Subpart that applies to this equipment: Mail this form along with a check for $152.90 to: Colorado Department of Public Health & Environment Section 05 — Stream Constituents APCD-SS-B1 4300 Cherry Creek Drive South Identify the VOC & HAP content of each applicable stream. Denver, CO 80246-1530 VOC Benzene Toluene Ethylbenzene Xylene n-Hexane For guidance on how to complete this APEN form: Stream (wt. %) o 0/o 0/o 0 (wt. /o) _ (wt. ) (wt. ) (wt. %) (wt. /a) Air Pollution Control Division: (303) 692-3150 Gas Varies depending on tank contents (oil or water) Small Business Assistance Program (SBAP): (303) 692-3148 or (303) 692-3175 Heavy Oil (or Heavy Liquid) 100 0.53 3.27 0.25 4.27 3.14 APEN forms: hap. www.cdphe.state.co.0 ap dow•nloadfomts.html Light Oil (or Light Liquid) 100 0.53 3.27 0.25 4.27 3.14 Application status: hap www.cdnhe.state.co.us ap _s.sspcpt.html Water/Oil 100 0.53 3.27 0.25 4.27 3.14 ® Submit a representative gas and liquid extended analysis (including BTEX) to support emission calculations ® Check box to request copy of draft permit prior to issuance. ® Check box to request copy of draft permit prior to public notice. FORM APCD-203 Page 1 of 2 CS Fugitives_AP_Form-APCD-203-Fugitive-Component-Leaks-APEN 20141020 AIR POLLUTANT EMISSION NOTICE (APEN) & Application for Construction Permit — Fugitive Component Leak Emissions Permit Number: Emission Source AIRS ID: / / Section 06 — Location Information (Provide Datum and either Lat/Long or UTM) Section 07 —Leak Detection & Repair (LDAR) & Control Information Horizontal Datum UTM UTM Fasting or UTM Northing or Method of Collection fox Check appropriate boxes to identify LDAR program conducted at this site: (NAD27, NAD83, Zone Longitude Latitude Location Data(e.g. map, GPS O LDAR per NSPS KKK ® No LDAR program WGS84) (12 of 13) (meters or degrees) (meters or degrees) GoogleEarth) O Other WGS84 13 535586.08 (m) 4439394.76 (m) GoogleEarth If LDAR per NSPS KKK with 10,000 ppmv leak definition: O Monthly monitoring. Control: 88%gas valve, 76%It. liq. valve, 68% It. liq. pump O Quarterly monitoring. Control: 70%gas valve, 61% It. liq. valve, 45%It. liq. pump Section 08 — Emission Factor Information Identify the emission factor used to estimate emissions under"E.F.", along with the units relating to the emission factor(e.g. lbfir'component). ® Check this box if you used Table 2-4 of U.S. EPA's 1995 Protocol for Equipment Leak Emission Estimates to estimate emissions. You do not need to enter the emission factors below if checked. Service Equipment Type Gas Heavy Oil (or Hea Liquid) Light Oil (or Light Liquid) Water/Oil Count' E.F. Units Count' E.F. Units Count' E.F. Units Count' E.F Units Connectors 187 17 191 364 Flanges 74 0 0 234 Open-Ended Lines 15 3 2 20 Pump Seals 0 0 1 4 - . Valves 6 3 32 92 _ Other 20 0 6 4 Count shall be the actual or estimated number of components in each type of service used to calculate the"Actual Calendar Year Emissions"below. a Estimated Count ❑ Actual Count conducted on the following date: Section 09 — Emissions Inventory Information & Emission Control Information ❑ Emission Factor Documentation attached Data year for actual calendar year emissions below (e.g. 2007): I Control Device Description Control Emission Factor Actual Calendar Year Emissions2 Requested Permitted Estimation Method Emissions' or Pollutant Efficiency Primary Secondary (Vo Reduction) Uncontrolled Basis Units Uncontrolled Controlled Uncontrolled Controlled Emission Factor (Tons/Year) (Tons/Year) (Tons/Year) (Tons/Year) Source VOC 4.65 Benzene Toluene 0.19 EPA-453/R-95- Ethylbenzene Identify in Section 07 Identify in Section 08 y 017, Table 2-4 Xylene 0.24 n-Hexane 0.18 Please use the APCD Non-Criteria Reportable Air Pollutant Addendum form to report pollutants not listed above. 'Annual emission fees will be based on actual emissions reported here. If left blank, annual emission fees will be based on requested emissions. ' You may request permitted emissions in excess of actual emissions to account for component count and gas composition variability. If Requested Permitted Emissions is left blank, emissions will be based on info. in Sec. 03 - 09. Section 10 pplicant Certifica — I eby ce 'Cy that all information contained herein and information submitted with this application is complete, true and correct. 10 - 1 - i (4 Josh Patterson VP of Operations Signa e of Person L gaily Autho = - • to Supply Data Date Name of Legally Authorized Person (Please print) Title Page 2 of 2 CS Fugitives_AP_Form-APCD-203-Fugitive-Component-I.eaks-APEN_20141020.doc AIR POLLUTANT EMISSION NOTICE (APEN) & Application for Construction Permit — Condensate Storage Tank(s)' Permit Number: GP01 [Leave blank unless APCD has already assigned a permit 4 & AIRS ID] Emission Source AIRS ID: / / Facility Equipment ID: Oil Heating Tank [Provide Facility Equipment ID to identify how this equipment is referenced within your organization.] Section 01 — Administrative Information Section 02 — Requested Action (Check applicable request boxes) Company Name: NGL Water Solutions DJ, LLC NAILS, or O Request for NEW INDIVIDUAL. permit SIC Code: 8 Request for coverage under GENERAL PERMIT Source Name: Oil Heating Tank ® GP01 O GP08 Source Location: C5 Salt Water Disposal Facility County: Weld O Request MODIFICATION to existing INDIVIDUAL permit (check boxes below) SW 'A SW 'A SECTION 29, T2N, R64W Elevation: 4591 Feet O Change process or equipment ❑ Change company name Mailing Address: 8207 West 20th Street, Suite B ZIP Code: 80634 O Change permit limit ❑ Transfer of ownership O Other Greeley, CO O APEN Submittal for Permit Exempt/Grandfathered source Person To Contact: Josh Patterson Phone Number: 970-356-5560 O APEN Submittal for update only (Please note blank APEN's will not be accepted) E-mail Address: jpatterson@highsierraenergy.com Fax Number: 970-356-5563 Addl. Info. & Notes: Section 03 — General Information For existing sources, operation began on: / / For new or reconstructed sources, the projected startup date is: / / 2014 This Storage Tank is ❑ ®Exploration & Production Midstream or Downstream hours.' days/ weeks: , Normal H f S Oi day 7 52 year Located at: (E&P) Site (Non-E&P) week Will this equipment be operated in any NAAQS nonattainment area? 0 Yes O No Are Flash Emissions anticipated at these tanks O Yes ® No Is actual annual average hydrocarbon liquid throughput 500 bbl/day? ® Yes O No If"yes", identify the stock tank gas-to-oil ratio: m.liter ► Are these condensate tanks subject to Colorado Oil and Gas Conservation Commission (C'OGCC) 805 series rules? If so, submit Form APCD-105. O Yes 0 No D. Arc you requesting_ 6 ton/yr VOC emissions, or are uncontrolled actual emissions _ 6 ton/yr? O Yes ® No General description of equipment purpose: Oil Heating Tank: 1 x 400 bbl Section 04 — Storage Tank(s) Information Requested Permit Limit: 219,000 bbl.' ear Colorado Department of Public Health and Environment Condensate qAir Pollution Control Division (APCD)This notice is valid for five Throughput: Actual: bbl/year Actual While Controls Operational: bbl/year (5) years. Submit a revised APEN prior to expiration of five-year Average API Gravity of Sales Oil: 47.0 degrees RVP of Sales Oil 3.2 term, or when a significant change is made (increase production, new Tank Design: Fixed Roof: ® Internal Floating Roof: O External Floating Roof: Elequipment, change in fuel type, etc). Mail this form along with a check for $152.90 per APEN for non- Storage # of Liquid Manifold Total Volume of Installation Date of most recent E&P, midstream and downstream sources or $152.90 for up to Date Of First Production Tank Storage Vessels in storage vessel in storage tank five (5) APENs for F.&P sources and $250 for each general permit ID Storage Tank Storage Tank (bbl) (Month/Year) (Month/Year) registration to: P4 1 400 Colorado Department of Public Health & Environment APCD-SS-Bl 4300 Cherry Creek Drive South Denver, CO 80246-1530 For guidance on how to complete this APEN form: Wells Serviced by this Storage Tank or Tank Battery (E&P Sites Only) Air Pollution Control Division: (303) 692-3150 API Number Name of Well Newly Reported Well Small Business Assistance Program (SBAP): (303) 692-3148 or - - 0 (303) 692-3175 - - 0 APEN forms: hut) %vww.colorado.gov cdphe oilga"4PENS - - 0 Application status: httn: µv,w.colorado.gos cdphc vermitstatus - - 0 - - 0 FORM A PUD-205 Page 1 of 2 CS OilHeatingTank_AP_Form-APCD-205-Condensate-Tanks-APEN 20141020.doc AIR POLLUTANT EMISSION NOTICE (APEN) & Application for Construction Permit — Condensate Storage Tank(s)t Permit Number: GP01 Emission Source AIRS ID: / / Section 05 — Stack Information (For Midstream sites only) Section 06 —Stack (Source, if no combustion) Location (Datum & either Lat/Long or UTM) rator Stack Base Stack Discharge Horizontal Datum U FM UTM Easting or UTM Northing or Method of Collection for Stack Elevation Height Above Temp Flow Rate Velocity Moisture (NAD27.NAD83, Zone Longitude Latitude Location Data(e.g.map, Ground Level (°F) (ACFM) (ft/sec) (%) ID No. (feet) WGS84) (12 or 13) (meters or degrees) (feet) gr ) (meters or degrees) GPS, GoogleEarth) P4 4951 WGS84 13 535586.08 (m) 4439394.76 (m) GoogleEarth Direction of stack outlet (check one): O Vertical O Vertical with obstructing raincap O Horizontal O Down O Other (Describe): Exhaust Opening Shape & Size (check one): O Circular: Inner Diameter(inches) = O Other: Length (inches) = Width (inches) = Section 07 — Control Device Information ❑ Vapor Recovery Unit (VRU) used for control of the Storage Tank(s) O Combustion Device used for control of the Storage Tank(s) Rating: MMBtu/hr Size: Make/Model: Type: Make.Model Requested VOC & HAP Control Efficiency: % VOC & HAP Control Efficiency: Requested: % Manufacturer Guaranteed: Annual time that VRU is bypassed (emissions vented): % Minimum temp. to achieve requested control: °F Waste gas heat content: Btu scf ❑ Closed loop system used for control of the storage tank(s) Constant pilot light? ❑ Yes O No Pilot burner rating: MMBtu'hr Description: O Describe Any Other: Section 08 — Gas/Liquids Separation Technology Information (E&P Sites Only) What is the pressure of the final separator vessel prior to discharge to the storage tank(s)? psig Please describe the separation process between the well and the storage tanks: Section 09 — Emissions Inventory Information & Emission Control Information 0 Emission Factor Documentation attached Data year for actual calendar yr. emissions below & throughput in Sec. 04(e.g. 2007): I Pollutant Emission Factor Actual Calendar Year Emission Requested Permitted Emissions Emission Factor Uncontrolled Basis Units Uncontrolled (Tons/Year) , Controlled (Tons/Year) Uncontrolled (Tons/Year) Controlled (Tons/Year) Data Source NOx VOC 1.66E-02 lb/bbl 1.82 E&P Tanks CO Benzene De minimis E&P Tanks Toluene De minimis E&P Tanks Ethylbenzene De minimis _ E&P Tanks Xylenes De minimis E&P Tanks n-Hexane 2.52E-03 lb/bbl 0.28 E&P Tanks 2,2,4-Tri tnet by l pentane Please use the APCD Non-Criteria Reportable Air Pollutant Addendum form to report pollutants not listed above. Section 10 —A plicant Certification r ye . that all information contained herein and information submitted with this application is complete, true and correct. Josh Patterson VP of Operations Signatu Person gall) Authoriz to Su ata Date Name of Legally Authorized Person (Please print) Title Y will be charged an additional APEN fee if the APEN is filled out incorrectly or is missing information and needs to be resubmitted. 2 Annual emissions fees will be based on actual emissions reported here. If left blank, annual emissions fees will be based on requested emissions. Additional Information 0 Attach a pressurized pre-flash condensate extended liquids analysis. RVP & API analysis of the post-flash oil Required: 0 Attach E&P Tanks input & emission estimate documentation (or equivalent simulation report/test results) 0 Check box to request copy of draft permit prior to issuance. ❑ Attach EPA TANKS emission analysis if emission estimates do not contain working/breathing losses 0 Check box to request copy of draft permit prior to public notice. FORM A PC D-205Page 2 of 2 CS OilHeatingTank_AP_Form-APCD-205-Condensate-Tanks-APEN 20141020.doc AIR POLLUTANT EMISSION NOTICE (APEN) & Application for Construction Permit — Condensate Storage Tank(s)' Permit Number: GP01 [Leave blank unless APCD has already assigned a permit 1$ & AIRS ID] Emission Source AIRS ID: / / Facility Equipment ID: Oil Tanks [Provide Facility Equipment ID to identify how this equipment is referenced within your organization.] Section 01 — Administrative Information Section 02 — Requested Action (Check applicable request boxes) Company Name: NGL Water Solutions DJ, LLC NAILS, or 0 Request for NEW INDIVIDUAL permit SIC Code: ® Request for coverage under GENERAL PERMIT Source Name: Oil Tanks ® GP0I 0 GP08 Source Location: C5 Salt Water Disposal Facility County: Weld 0 Request MODIFICATION to existing INDIVIDUAL permit (check boxes below) SW '/ SW '4 SECTION 29, T2N, R64W Elevation: 4951 Feet 0 Change process or equipment 0 Change company name Mailing Address: 8207 West 20th Street, Suite B ZIP Code: 80634 0 Change permit limit 0 Transfer of ownership 0 Other Greeley, CO 0 APEN Submittal for Permit Exempt/Grandfathered source Person To Contact: Josh Patterson Phone Number: 970-356-5560 0 APEN Submittal for update only (Please note blank APEN's will not be accepted) E-mail Address: jpatterson@highsierraenergy.com Fax Number: 970-356-5563 Addl. Info. a & Notes: Section 03 — General Information For existing* sources, operation began on: / / For new or reconstructed sources, the projected startup date is: / / 2014 This Storage Tank is Exploration & Production Midstream or Downstream hours.' days/ weeks/ Located at: ❑ (E&P) Site ® Normal Hours of Source Operation: 24 7 52 year (Non-E&P) Site p day week Will this equipment be operated in any NAAQS nonattainment area? ® Yes 0 No Are Flash Emissions anticipated at these tanks 0 Yes ® No Is actual annual average hydrocarbon liquid throughput _ 500 bbl/day? ® Yes 0 No If"yes", identify the stock tank gas-to-oil ratio: m3/liter ► Are these condensate tanks subject to Colorado Oil and Gas Conservation Commission (COGCC) 805 series rules? If so, submit Form APCD-105. 0 Yes 8 No ► Are you requesting_ 6 ton/yr VOC emissions, or are uncontrolled actual emissions > 6 ton/yr? 0 Yes ® No General description of equipment purpose: Oil Tanks: 3 x 400 bbl Section 04 — Storage Tank(s) Information Requested Permit Limit: 2l9 000 bbl/year Colorado Department of Public Health and Environment Condensate qAir Pollution Control Division (APCD)This notice is valid for five Throughput: Actual: bbl/year Actual While Controls Operational: bbl/year (5) years. Submit a revised APEN prior to expiration of five-year Average API Gravity of Sales Oil: 47.0 degrees RVP of Sales Oil 3.2 term, or when a significant change is made (increase production, new Tank Design: Fixed Roof: ® Internal Floating Roof: 0 External Floating Roof: ❑ equipment, change in fuel type, etc). Mail this form along with a check for $152.90 per APEN for non- Storage # of Liquid Manifold Installation Date of most recent E&P, midstream and downstream sources or $152.90 for up to Total Volume of Date Of First Production Tank Storage Vessels in storage vessel in storage tank five (5) APENs for E&P sources and $250 for each general permit ID Storage Tank Storage Tank (bbl) (Month/Year) (Month/Year) registration to: T3 3 1200 Colorado Department of Public Health & Environment APCD-SS-B1 4300 Cherry Creek Drive South Denver, CO 80246-1530 For guidance on how to complete this APEN form: Wells Serviced by this Storage Tank or Tank Battery (E&P Sites Only) API Number Name of Well Newly Reported Well Air Pollution Control Division: (303) 692-3150 0 Small Business Assistance Program (SBAP): (303) 692-3148 or - - (303) 692-3175 - - 0 APEN forms: Imp nw.colorado.go; cdphe oilgasAPENS - - 0 Application status: http www.colorado.go' •dphe pennitstatus - - 0 FORM A PCD-205 Page 1 of 2 C5 OilTanks AP_Form-APCD-205-Condensate-Tanks-APEN 20141020.doc AIR POLLUTANT EMISSION NOTICE (APEN) & Application for Construction Permit — Condensate Storage Tank(s)' Permit Number: GP01 Emission Source AIRS ID: / / Section 05 — Stack Information (For Midstream sites only) Section 06 —Stack (Source, if no combustion) Location (Datum & either Lat/Long or UTM) Operator Stack Base Stack Discharge Height Above Temp. Flow Rate Velocity Moisture Horizontal Datum UTM UTM Fasting or UTM Northing or Method of Collection for Stack Etc,ation Ground Level (°F) (ACFM) (ft'sec) (%) (NAD27,NAD83, Zone Longitude Latitude Location Data (e.g. map, ID No (feet) (feet) WGS84) (12 or 13) (meters or degrees) (meters or degrees) GPS, GoogicEarth) T3 4951 WGS84 13 535586.08 (m) 4439394.76 (m) GoogleEarth Direction of stack outlet (check one): O Vertical O Vertical with obstructing raincap O Horizontal O Down O Other (Describe): Exhaust Opening Shape & Size (check one): O Circular: Inner Diameter(inches) = O Other: Length (inches) = Width (inches) = Section 07 — Control Device Information ❑ Vapor Recovery Unit (VRU) used for control of the Storage Tank(s) O Combustion Device used for control of the Storage Tank(s) Rating: MMBtu/hr Size: Make/Model: Type: Makc.Model Requested VOC & HAP Control Efficiency: % VOC & HAP Control Efficiency: Requested: % Manufacturer Guaranteed: % Annual time that VRU is bypassed (emissions vented): % Minimum temp. to achieve requested control: °F Waste gas heat content: Btwscf O Closed loop system used for control of the storage tank(s) Constant pilot light? O Yes O No Pilot burner rating: MMBtwhr Description: O Describe Any Other: Section 08 — Gas/Liquids Separation Technology Information (E&P Sites Only) What is the pressure of the final separator vessel prior to discharge to the storage tank(s)? psig Please describe the separation process between the well and the storage tanks: Section 09 — Emissions Inventory Information & Emission Control Information 9 Emission Factor Documentation attached Data year for actual calendar yr. emissions below & throughput in Sec. 04 (e.g. 2007): I 1 Emission Factor Actual Calendar Year Emission Requested Permitted Emissions Emission Factor Pollutant _ Uncontrolled Basis Units Uncontrolled (Tons/Year) Controlled (Tons/Year) Uncontrolled (Tons/Year) Controlled (Tons/Year) Data Source NOx VOC 1.92E-02 lb/bbl 2.10 E&A Tanks CO Benzene De minimis E&A Tanks Toluene De minimis E&A Tanks Ethylbenzene De minimis E&A Tanks Xylenes De minimis E&A Tanks n-Hexane 3.00E-03 lb/bbl 033 E&A Tanks 2,2,4-Trimethylpentane Please use the APCD Non-Criteria Reportable Air Pollutant Addendum form to report pollutants not listed above. Section 0 — pplicant Certificati -, r by certify that all information contained herein and information submitted with this application is complete, true and correct. • f"� 9 ~ 1 - Pi Josh Patterson VP of Operations Signa erson gaily Autho - es ti upply Data Date Name of Legally Authorized Person (Please print) Title will be charged an additional APEN fee if the APEN is filled out incorrectly or is missing information and needs to be resubmitted. 2 Annual emissions fees will be based on actual emissions reported here. If left blank, annual emissions fees will be based on requested emissions. Additional Information 9 Attach a pressurized pre-flash condensate extended liquids analysis. RVP & API analysis of the post-flash oil Required: 9 Attach E&P Tanks input & emission estimate documentation (or equivalent simulation report/test results) 9 Check box to request copy of draft permit prior to issuance. ❑ Attach EPA TANKS emission analysis if emission estimates do not contain working/breathing losses 9 Check box to request copy of draft permit prior to public notice. FORM A PCD-205 Page 2 of 2 C5 OilTanks_AP_Fonn-APCD-205-Condensate-Tanks-APEN 20141020.doc AIR POLLUTANT EMISSION NOTICE (APEN) & Application for Construction Permit — Condensate Storage Tank(s)' Permit Number: GP01 [Leave blank unless APCD has already assigned a permit u & AIRS ID] Emission Source AIRS ID: / / Facility Equipment ID: Slop Oil Tank [Provide Facility Equipment ID to identify how this equipment is referenced within your organization.] Section 01 — Administrative Information Section 02 — Requested Action (Check applicable request boxes) Company Name: NGL Water Solutions DJ, LLC NAILS, or ❑ Request for NEW INDIVIDUAL permit SIC Code: ® Request for coverage under GENERAL PERMIT Source Name: Slop Oil Tank ® GPO' 0 GP08 Source Location: C5 Salt Water Disposal Facility County: Weld 0 Request MODIFICATION to existing INDIVIDUAL permit (check boxes below) SW '4 SW '4 SECTION 29, T2N, R64W Elevation: 4951 Feet 0 Change process or equipment 0 Change company name Mailing Address: 8207 West 20'" Street, Suite B ZIP Code: 80634 0 Change permit limit 0 Transfer of ownership ❑ Other Greeley, CO 0 APEN Submittal for Permit Exempt/Grandfathered source Person To Contact: Josh Patterson Phone Number: 970-356-5560 0 APEN Submittal for update only (Please note blank APEN's will not be accepted) E-mail Address: jpatterson@highsierraenergy.com Fax Number: 970-356-5563 Addl. Info. & Notes: Section 03 — General Information For existing sources, operation began on: / / For new or reconstructed sources, the projected startup date is: / / 2014 This Storage Tank is ❑ ®Exploration & Production Midstream or Downstream hours/ days. weeks/ day 7 52 year Normal week Will this equipment be operated in any NAAQS nonattainment area? ® Yes 0 No Are Flash Emissions anticipated at these tanks 0 Yes ® No Is actual annual average hydrocarbon liquid throughput _ 500 bb)/day? ® Yes ❑ No If"yes", identify the stock tank gas-to-oil ratio: m3/liter ► Are these condensate tanks subject to Colorado Oil and Gas Conservation Commission (COGCC) 805 series rules? If so, submit Form APCD-105. ❑ Yes ® No ► Arc you requesting≥ 6 ton/yr VOC emissions, or are uncontrolled actual emissions _ 6 ton/yr? 0 Yes ® No General description of equipment purpose: Slop Oil Tank: 1 x 400 bbl Section 04 — Stora2e Tank(s) Information Requested Permit Limit: 219,000 bbl.year Colorado Department of Public Health and Environment Condensate qy Air Pollution Control Division (APCD)This notice is valid for five Throughput: Actual: bbl/year Actual While Controls Operational: bbl.year (5) years. Submit a revised APEN prior to expiration of five-year Average API Gravity of Sales Oil: 47.0 degrees RVP of Sales Oil 3.2 term, or when a significant change is made (increase production, new Tank Design: Fixed Roof: ® Internal Floating Roof: 0 External Floating Roof Elequipment, change in fuel type, etc). Mail this form along with a check for $152.90 per APEN for non- Storage # of Liquid Manifold Total Volume of Installation Date of most recent Date Of First Production E&P, midstream and downstream sources or $152.90 for up to Tank Storage Vessels in storage vessel in storage tank five (5) APENs for E&P sources and $250 for each general permit Storage Tank Storag ID g (Month/Year) registration to: T4 1 400 Colorado Department of Public Health & Environment APCD-SS-BI 4300 Cherry Creek Drive South Denver, CO 80246-1530 For guidance on how to complete this APEN form: Wells Serviced by this Storage Tank or Tank Battery (E&P Sites Only) Air Pollution Control Division: (303) 692-3150 API Number Name of Well Newly Reported Well Small Business Assistance Program (SBAP): (303) 692-3148 or - - 0 - (303) 692-3175 - - 0 APEN forms: http: www.colorado.gco% cdahe oilgasAPENS - - 0 Application status: httm www.colorado.goN cciplit nermitstatus - - 0 - - 0 FORM A PCD-205 Page 1 of 2 C5 SlopOilTank_AP_Forn-APCD-205-Condensate-Tanks-APEN 20!41020.doc AIR POLLUTANT EMISSION NOTICE (APEN) & Application for Construction Permit — Condensate Storage Tank(s)' Permit Number: GP01 Emission Source AIRS ID: / / Section 05 — Stack Information (For Midstream sites only) Section 06 —Stack (Source, if no combustion) Location (Datum & either Lat/Long or UTM) Stack Discharge Operator Stack Base Horizontal Datum UTM UTM Lasting or UTM Northing or Method of Collection for Stack Elevation Height Above Temp. Flow Rate Velocity Moisture Moist Ground Level (°F) (ACFM) (ft/sec) (%) (NAD27, NAD83, Zone Longitude Latitude Location Data(e.g. map, ID No. (feet) (feet) WGS84) (12 or 13) (meters or degrees) (meters or degrees) GPS, GoogleEarth) T4 4951 WGS84 13 535586.08 (m) 4439394.76 (m) GoogleEarth Direction of stack outlet (check one): 0 Vertical O Vertical with obstructing raincap 0 Horizontal 0 Down O Other (Describe): Exhaust Opening Shape & Size (check one): O Circular: Inner Diameter(inches) = O Other: Length (inches) = Width (inches) = Section 07 — Control Device Information ❑ Vapor Recovery Unit (VRU) used for control of the Storage Tank(s) O Combustion Device used for control of the Storage Tank(s) Rating: MMBtu/hr Size: Make Model: Type: Make/Model Requested VOC & HAP Control Efficiency: % VOC & HAP Control Efficiency: Requested: % Manufacturer Guaranteed: % Annual time that VRU is bypassed (emissions vented): % Minimum temp. to achieve requested control: °F Waste gas heat content: But sef O Closed loop system used for control of the storage tank(s) Constant pilot light? O Yes O No Pilot burner rating: MMBtu/hr Description: O Describe Any Other: Section 08 — Gas/Liquids Separation Technology Information (E&P Sites Only) What is the pressure of the final separator vessel prior to discharge to the storage tank(s)? psig Please describe the separation process between the well and the storage tanks: Section 09 — Emissions Inventory Information & Emission Control Information ® Emission Factor Documentation attached Data year for actual calendar yr. emissions below & throughput in Sec.04 (e.g. 2007): l Emission Factor Actual Calendar Year Emission Requested Permitted Emissions Emission Factor Pollutant Uncontrolled Basis Units Uncontrolled (Tons/Year) Controlled (Tons/Year) _ Uncontrolled (Tons/Year) Controlled (Tons/Year) Data Source NOx VOC 1.12E-02 lb/bbl 1.22 E&P Tanks CO Benzene De minimis E&P Tanks Toluene De minimis E&P Tanks Ethylbenzene De minimis E&P Tanks Xylenes De minimis E&P Tanks n-Hexane 1.72E-03 lb/bbl 0.19 E&P Tanks 2,2,4-Trimethylpentane Please use the APCD Non-Criteria Reportable Air Pollutant Addendum form to report pollutants not listed above. Section 1 Applicant Certific ' - I hereby certify that all information contained herein and information submitted with this application is complete, true and correct. ^3I "I'4 Josh Patterson VP of Operations Sig re of Person Legal!) Autho zed to Supply Data Date Name of Legally Authorized Person (Please print) Title ou will be charged an additional APEN fee if the APEN is filled out incorrectly or is missing information and needs to be resubmitted. 2 Annual emissions fees will be based on actual emissions reported here. If left blank, annual emissions fees will be based on requested emissions. Additional Information ® Attach a pressurized pre-flash condensate extended liquids analysis, RVP & API analysis of the post-flash oil Required: 0 Attach E&P Tanks input & emission estimate documentation(or equivalent simulation report/test results) 0 Check box to request copy of draft permit prior to issuance. O Attach EPA TANKS emission analysis if emission estimates do not contain working/breathing losses 0 Check box to request copy of draft permit prior to public notice. FORM A PC D-205 j Page 2 of 2 C5 Slop0ilTank_AP_Form-APCD-205-Condensate-Tanks-APEN_20141020.doc AIR POLLUTANT EMISSION NOTICE (APEN) & Application for Construction Permit — Condensate Storage Tank(s)' Permit Number: GP01 [Leave blank unless APCD has already assigned a permit# & AIRS ID] Emission Source AIRS ID: / / Facility Equipment ID: Sale Oil Tank [Provide Facility Equipment ID to identify how this equipment is referenced within your organization.] Section 01 — Administrative Information Section 02 — Requested Action (Check applicable request boxes) Company Name: NGL Water Solutions DJ, LLC NAILS, or O Request for NEW INDIVIDUAL permit SIC Code: ® Request for coverage under GENERAL PERMIT Source Name: Sale Oil Tank ® GP0I O GP08 Source Location: CS Salt Water Disposal Facility County: Weld O Request MODIFICATION to existing INDIVIDUAL permit (check boxes below) SW ''4 SW ''44 SECTION 29, T2N, R64W Elevation: 4951 Feet O Change process or equipment ❑ Change company name Mailing Address: 8207 West 20th Street, Suite B ZIP Code: 80634 O Change permit limit O Transfer of ownership O Other Greeley, CO O APEN Submittal for Permit Exempt/Grandfathered source Person To Contact: Josh Patterson Phone Number: 970-356-5560 O APEN Submittal for update only (Please note blank APEN's will not be accepted) E-mail Address: jpatterson@highsierraenergy.com Fax Number: 970-356-5563 Addl. Info. & Notes: Section 03 — General Information For existing sources, operation began on: / / For new or reconstructed sources, the projected startup date is: / / 2014 This Storage Tank is ❑ ®Exploration & Production Midstream or Downstream hours/ days/ weeks" Hours of Source Operation: 24 Normal y year 52_ week Will this equipment be operated in any NAAQS nonattainment area? ® Yes O No Are Flash Emissions anticipated at these tanks ❑ Yes ® No Is actual annual average hydrocarbon liquid throughput _ 500 bbl/day? ® Yes O No If"yes", identify the stock tank gas-to-oil ratio: m3/liter ► Are these condensate tanks subject to Colorado Oil and Gas Conservation Commission (COGCC) 805 series rules? If so, submit Form APCD-105. O Yes 0 No ► Are you requesting_ 6 ton/yr VOC emissions, or are uncontrolled actual emissions _ 6 ton/yr? O Yes 0 No General description of equipment purpose: Sale Oil Tank: I x 400 bbl Section 04 - Storage Tank{s) Information Colorado Department of Public Health and Environment Condensate Requested Permit Limit: 219,000 bblryear Air Pollution Control Division (APCD)This notice is valid for five Throughput: Actual: bbl/year Actual While Controls Operational: bbl/year (5) years. Submit a revised APEN prior to expiration of five-year Average API Gravity of Sales Oil: 47.0 degrees RVP of Sales Oil 3.2 term, or when a significant change is made (increase production, new Tank Design: Fixed Roof: 0 Internal Floating Roof: ElExternal Floating Roof ❑ equipment, change in fuel type, etc). Mail this form along with a check for $152.90 per APEN for non- Storage # of Liquid Manifold Total Volume of Installation Date of most recent Date Of First Production E&P, midstream and downstream sources or $152.90 for up to Tank Storage Vessels in storage vessel in storage tank five (5) APENs for E&P sources and $250 for each general permit ID Storage Tank g (Month/Year) registration to: T5 l 400 Colorado Department of Public Health & Environment " APCD-SS-BI 4300 Cherry Creek Drive South Denver, CO 80246-1530 For guidance on how to complete this APEN form: Wells Serviced by this Storage Tank or Tank Battery (E&P Sites Only) Air Pollution Control Division: (303) 692-3150 API Number Name of Well Newly Reported Well Small Business Assistance Program (SBAP): (303) 692-3148 or - - 0 (303) 692-3175 - - 0 APEN forms: httn www.colorado.to' cdnhc oiliasAPENS - - 0 Application status: Imp: uwlv.colorado.go, cdnhe permitstatus - - 0 - - 0 FORM APCD-20S Page 1 oft C5SaleOilTank_AP_Forn-APCD-205-Condensate-Tanks-APEN 20141020.doc AIR POLLUTANT EMISSION NOTICE (APEN) & Application for Construction Permit — Condensate Storage Tank(s)' Permit Number: GP01 Emission Source AIRS ID: / / Section 05 — Stack Information (For Midstream sites only) Section 06 —Stack (Source, if no combustion) Location (Datum_her Lat/Long or UTM) Stack Discharge Operator Stack Base Horizontal Datum UTM UTM Easting or UTM Northing or Method of Collection for Stack Height Above Temp. Flow Rate Velocity Moisture ID No. Elevation Ground Level (°F) (ACFM) (ft/sec) (°/,) (NAD27,NAD83, Zone Longitude Latitude Location Data(e.g. map, (feet) (feet) WGS84) (12 or 13) (meters or degrees) (meters or degrees) GPS, GoogleEarth) T5 4951 WGS84 13 535586.08 (m) 4439394.76 (m) GoogleEarth Direction of stack outlet (check one): O Vertical ❑ Vertical with obstructing raincap O Horizontal O Down 0 Other (Describe): Exhaust Opening Shape & Size (check one): O Circular: Inner Diameter(inches) = O Other: Length (inches) = Width (inches) = Section 07 — Control Device Information O Vapor Recovery Unit (VRU) used for control of the Storage Tank(s) O Combustion Device used for control of the Storage Tank(s) Rating: MMBtu/hr Size: Make/Model: Type: Make/Model Requested VOC & HAP Control Efficiency: % VOC & HAP Control Efficiency: Requested: % Manufacturer Guaranteed: % Annual time that VRU is bypassed (emissions vented): % Minimum temp. to achieve requested control: °F Waste gas heat content: Btu'scf O Closed loop system used for control of the storage tank(s) Constant pilot light? O Yes O No Pilot burner rating: MMBtu'hr Description: O Describe Any Other: Section 08 — Gas/Liquids Separation Technology Information (E&P Sites Only) + What is the pressure of the final separator vessel prior to discharge to the storage tank(s)? psig Please describe the separation process between the well and the storage tanks: Section 09 — Emissions Inventory Information & Emission Control Information ® Emission Factor Documentation attached Data year for actual calendar yr. emissions below & throughput in Sec. 04 (e.g.2007): I I Pollutant Emission Factor Actual Calendar Year Emission Requested Permitted Emissions Emission Factor Uncontrolled Basis Units Uncontrolled (Tons/Year) Controlled (Tons/Year) Uncontrolled(Tons/Year) Controlled (Tons/Year) Data Source NOx VOC 1.12E-02 lb/bbl 1.22 E&P Tanks CO Benzene De minimis E&P Tanks Toluene De minimis E&P Tanks Ethylbenzene _ De minimis E&P Tanks Xylenes De minimis E&P Tanks n-Hexane 1.72E-03 lb/bbl 0.19 E&P Tanks 2,2,4-Trimethylpentane Please use the APCD Non-Criteria Reportable Air Pollutant Addendum form to report pollutants not listed above. Sectio 10 Applicant Certification - I h re certify that all information contained herein and information submitted with this application is complete, true and correct. /0 `(3/ "/9 Josh Patterson VP of Operations Sign re of Perso Legally Authonzed upp y ata Date Name of Legally Authorized Person (Please print) Title u will be charged an additional APEN fee if the APEN is filled out incorrectly or is missing information and needs to be resubmitted. -- Annual emissions fees will be based on actual emissions reported here. If left blank, annual emissions fees will be based on requested emissions. Additional Information ® Attach a pressurized pre-flash condensate extended liquids analysis. RVP& API analysis of the post-flash oil Required: ® Attach E&P Tanks input & emission estimate documentation (or equivalent simulation report'test results) 0 Check box to request copy of draft permit prior to issuance. ❑ Attach EPA TANKS emission analysis if emission estimates do not contain working/breathing losses _ 0 Check box to request copy of draft permit prior to public notice. FORM A PCO-205 Page 2 of 2 C5 SaleOilTank_All_Form-APCD-205-Condensate-Tanks-APEN 20141020.doc AIR POLLUTANT EMISSION NOTICE (APEN) & Application for Construction Permit — Produced Water Storage Tank(s)' Permit Number: GP05 [Leave blank unless APCD has already assigned a permit # & AIRS ID] Emission Source AIRS ID: / / Facility Equipment ID: Desand Tanks [Provide Facility Equipment ID to identify how this equipment is referenced within your organization.] Section 01 — Administrative Information Section 02 — Requested Action (Check applicable request boxes) Company Name: NGL Water Solutions DJ, LLC NAILS, or O Request for NEW INDIVIDUAL permit ® SIC Code: Request for coverage under GENERAL PERMIT Source Name: Desand Tanks ® GP05 O GP08 Source Location: C5 Salt Water Disposal Facility Count) : Weld O Request MODIFICATION to existing INDIVIDUAL permit (check boxes below) SW 'A SW ''4 SECTION 29, T2N, R64W Elevation: 4951 Feet ❑ Change process or equipment O Change company name Mailing Address: 8207 West 20th Street, Suite B ZIP Code: 80634 O Change permit limit O Transfer of ownership O Other Greeley, CO O APEN Submittal for Permit Exempt/Grandfathered source Person To Contact: Josh Patterson Phone Number: 970-356-5560 O APEN Submittal for update only (Please note blank APEN's will not be accepted) E-mail Address: jpatterson@bighsierraenergy.com Fax Number: 970-356-5563 Addl. Info. & Notes: Section 03 - General Information For existing sources, operation began on: / / For new or reconstructed sources, the projected startup date is: / / 2014 This Storage Tank is Exploration & Production Midstream or Downstream hours days/ weeks/ Located at: ❑ (E&P) ® Normal Hours of Source Operation: 24 day 7 week 52 year Site (Non-E&P) Site Will this equipment be operated in any NAAQS nonattainment area? ® Yes O No Are Flash Emissions anticipated at these tanks O Yes ® No IN. Are these produced water tanks located at a commercial facility that accepts oil production wastewater for processing? ® Yes O No ► Do these storage tanks contain less than I% by volume crude oil on an annual average basis? O Yes ® No ► Are these produced water tanks subject to Colorado Oil and Gas Conservation Commission (COGCC) 805 series rules? If so, submit Form APCD-105. O Yes ® No ► Are you requesting 6 ton yr VOC emissions, or are uncontrolled actual emissions_ 6 ton/yr? O Yes ® No General description of equipment purpose: Desand Tanks: 2 x 700 bbl Section 04 - Storage Tank(s) Information Colorado Department of Public Health and Environment Produced Water Requested Permit Limit: 7,300,000 bbl.year Air Pollution Control Division (APCD)This notice is valid for five Throughput: (5) years. Submit a revised APEN prior to expiration of five-year Actual: bbl/year Actual While Controls Operational: bbl/year term, or when a significant change is made (increase production, new Tank Design: Fixed Roof: ® Internal Floating Roof: O External Floating Roof: O equipment, change in fuel type, etc). Mail this form along with a check for $152.90 per APEN for non- Storage # of Liquid Manifold Total Volume of Installation Date of most recent Date Of First Production E&P, midstream and downstream sources or $152.90 for up to Tank Storage Vessels in storage vessel in storage tank five (5) APENs for E&P sources and $250 for each general permit ID Storage Tank Storage Tank (bbl) (Month/Year) (Month/Year) registration to: P1 2 1,400 Colorado Department of Public Health & Environment APCD-SS-BI 4300 Cherry Creek Drive South Denver, CO 80246-1530 Wells Serviced by this Storage Tank or Tank Battery (E&P Sites Only) For guidance on how to complete this APEN form: API Number Name of Well Newly Reported Well Air Pollution Control Division: (303) 692-3150 - - 0 Small Business Assistance Program (SBAP): (303) 692-3148 or - - ' El (303) 692-3175 APEN forms: help. •www.colorado.go'• cdphe oilgasAPENS 0 Application status: http: ��ww.colorado.teo' cdphc pemtitstatus - - 0 FORM APCD-207 Page 1 of 2 C5 DesandTanks_AP_Form-APCD-207-ProducedWaterTank-APEN 20141020.doc AIR POLLUTANT EMISSION NOTICE (APEN) & Application for Construction Permit — Produced Water Storage Tank(s)' Permit Number: GP05 Emission Source AIRS ID: / / Section 05 - Stack Information (For Midstream sites only) Section 06 —Stack (Source, if no combustion) Location (Datum & either Lat/Long or UTM) Stack Discharge Operator Stack Base Horizontal Datum UTM UTM Easting or UTM Northing or Method of Collection for Stack Elevation Height Above Temp. Flow Rate Velocity Moisture Ground Level (°F) (ACFM) (ft/sec) (%) (NAD27.NAD83, Zone Longitude Latitude Location Data (e.g. map, ID No. (feet) (feet) WGS84) (12 or 13) (meters or degrees) (meters or degrees) GPS, GoogleEarth) PI 4951 WGS84 13 535586.08 (m) 4439394.76 (m) GoogleEarth Direction of stack outlet (check one): ❑ Vertical O Vertical with obstructing raincap O Horizontal O Down O Other (Describe): Exhaust Opening Shape & Size (check one): O Circular: Inner Diameter(inches) = ❑ Other Length (inches) = Width (inches) = Section 07 — Control Device Information ❑ Vapor Recovery Unit (VRU) used for control of the Storage Tank(s) O Combustion Device used for control of the Storage Tank(s) Rating: MMBtu/hr Size: Make.'Model: Type: Make Model Requested VOC & HAP Control Efficiency: % VOC & HAP Control Efficiency: Requested: % Manufacturer Guaranteed: % Annual time that VRU is bypassed (emissions vented): % Minimum temp. to achieve requested control: °F Waste gas heat content: Btu'scf ❑ Closed loop system used for control of the storage tank(s) Constant pilot light? O Yes O No Pilot burner rating: MMBtu hr Description: O Describe Any Other: Section 08 — Gas/Liquids Separation Technoloey Information (E&P Sites Only) What is the pressure of the final separator vessel prior to discharge to the storage tank(s)? psig Please describe the separation process between the well and the storage tanks: Section 09 — Emissions Inventory Information & Emission Control Information ® Emission Factor Documentation attached Data year for actual calendar yr. emissions below& throughput in Sec. 04 (e.g. 2007): I Emission Factor Actual Calendar Year Emission' Requested Permitted Emissions Estimation Method or Pollutant Uncontrolled Controlled Uncontrolled Controlled Emission Factor Uncontrolled Basis Units (Tons/Year) (Tons,Year) (Tons/Year) (Tons/Year) Source NOx VOC 3.48E-04 lb/bbl 1.27 EPA Tanks CO Benzene De minimis EPA Tanks Toluene De minimis EPA Tanks Ethylbenzene De minimis EPA Tanks Xylenes De minimis EPA Tanks n-Hexane -5.30E-05 Ib/bbl 0.19 EPA Tanks 2,2,4-Trimethylpentane Please use the APCD Non-Criteria Reportable Air Pollutant Addendum form to report pollutants not listed above. Section 10 licant Certificatio - r by certify that all information contained herein and information submitted with this application is complete, true and correct. /0 t3/ / y Josh Patterson VP of Operations Sign e of Person Legall) Auth rized to pply Data Date Name of Legally Authorized Person (Please print) Title ou will be charged an additional APEN fee if the APEN is filled out incorrectly or is missing information and needs re-submittal. Annual emissions fees will be based on actual emissions reported here. If left blank.annual emissions fees will be based on requested emissions. Additional Information Attach produced water laboratory analysis,stack test results and associated emissions calculations if you are ® Check box to request copy of draft permit prior to issuance. Required: El requesting a site specific emissions factor according to the guidance in PS Memo 14-03 ® Check box to request copy of draft permit prior to public notice. FORM A PCD-207 Page 2 of 2 C5 DesandTanks_AP_Form-APCD-207-ProducedWaterTank-APEN 20141020.doc AIR POLLUTANT EMISSION NOTICE (APEN) & Application for Construction Permit — Produced Water Storage Tank(s)' Permit Number: GP05 [Leave blank unless APCD has already assigned a permit # & AIRS ID] Emission Source AIRS ID: / / Facility Equipment ID: Sand and Oil Removal Tanks [Provide Facility Equipment ID to identify how this equipment is referenced within your organization.] Section 01 — Administrative Information Section 02 — Requested Action (Check applicable request boxes) Company Name: NGL Water Solutions DJ, LLC NAILS, or 0 Request for NEW INDIVIDUAL permit ® SIC Code: Request for coverage under GENERAL PERMIT Source Name: Sand and Oil Removal Tanks ® GP05 ❑ GP08 Source Location: C5 Salt Water Disposal Facility County: Weld ❑ Request MODIFICATION to existing INDIVIDUAL permit (check boxes below) SW '/ SW '/4 SECTION 29, T2N, R64W Elevation: 4951 Feet ❑ Change process or equipment 0 Change company name Mailing Address: 8207 West 20th Street, Suite B ZIP Code: 80634 0 Change permit limit 0 Transfer of ownership ❑ Other Greeley, CO ❑ APEN Submittal for Permit Exempt/Grandfathered source Person To Contact: Josh Patterson Phone Number: 970-356-5560 0 APEN Submittal for update only (Please note blank APEN's will not be accepted) AE-mail Address: jpatterson@highsierraenergy.com Fax Number: 970-356-5563 & No info. & Notes: Section 03 — General Information For existing sources, operation began on: / / For new or reconstructed sources, the projected startup date is: / / 2014 This Storage Tank is Exploration & Production Midstream or Downstream hours. days. weeks/ Located at: ❑ (E&P) Site ® Normal H f S Oi 7 52 day year week Will this equipment be operated in any NAAQS nonattainment area? ® Yes 0 No Are Flash Emissions anticipated at these tanks 0 Yes ® No ► Are these produced water tanks located at a commercial facility that accepts oil production wastewater for processing? ® Yes 0 No ► Do these storage tanks contain less than 1% by volume crude oil on an annual average basis? 0 Yes ® No ► Are these produced water tanks subject to Colorado Oil and Gas Conservation Commission (COGCC) 805 series rules? If so, submit Form APCD-105. 0 Yes ® No ► Are you requesting _ 6 ton/yr VOC emissions. or are uncontrolled actual emissions_ 6 ton/yr? 0 Yes ® No General description of equipment purpose: Saud and Oil Removal Tanks: 2 x 1000 bbl Section 04 - Storage Tank(s) Information Colorado Department of Public Health and Environment Produced Water Requested Permit Limit: 7,300,000 bbl.'year Air Pollution Control Division (APCD)This notice is valid for five (5) years. Submit a revised APEN prior to expiration of five-year Throughput: Actual: bbl/year Actual While Controls Operational: bbl/year term, or when a significant change is made (increase production, new Tank Design: Fixed Roof ® Internal Floating Roof: 0 External Floating Roof ❑ equipment, change in fuel type, etc). Mail this form along with a check for $152.90 per APEN for non- Storage # of Liquid Manifold Installation Date of most recent Date Of First Productionup Tank Storage Vessels in Total Volume of storage vessel in storage tank E&P, midstream and downstream sources or $152.90 for to ID Storage Tank Storage Tank (bbl) (Month/Year) (Month/Year) five (5) APENs for E&P sources and $250 for each general permit registration to: P2 2 2,000 Colorado Department of Public Health & Environment APCD-SS-B1 4300 Cherry Creek Drive South Denver, CO 80246-1530 Wells Serviced by this Storage Tank or Tank Battery(E&P Sites Only) For guidance on how to complete this APEN form: API Number Name of Well Newly Reported Well Air Pollution Control Division: (303) 692-3150 - - 0 Small Business Assistance Program (SBAP): (303) 692-3148 or ❑ (303) 692-3175 - APEN forms: Imo www.colorado.got alai. nilgasAPENS Application status: biro: www.Colorado.QM'icdphe'permitstatus - - 0 O FORM A PC D-207 Page 1 of 2 C5 SandOilRemovalTanks_AP_Form-APCD-207-ProducedWaterTank-APEN 20141020.doc AIR POLLUTANT EMISSION NOTICE (APEN) & Application for Construction Permit — Produced Water Storage Tank(s)' Permit Number: GP05 Emission Source AIRS ID: / / Section 05 — Stack Information (For Midstream sites only) Section 06 -Stack (Source, if no combustion) Location (Datum & either Lat/Long or UTM) Stack Discharge Operator Stack Base e Height Above Temp Flow Rate Velocity Moisture Horizontal Datum UTM UTM Fasting or U I M Northing or Method of Collection for Stack Elevation Ground Level (°F) (ACFM) (ft/see) (%) (NAD27,NAD83, Zone Longitude Latitude Location Data(e.g.map, ID No (feet) (feet) WGS84) (12 or 13) (meters or degrees) (meters or degrees) GPS, GoogleEarth) P2 4951 WGS84 13 535586.08 (m) 4439394.76 (m) GoogleEarth Direction of stack outlet (check one): O Vertical O Vertical with obstructing raincap O Horizontal O Down O Other (Describe): Exhaust Opening Shape & Size (check one): O Circular: Inner Diameter(inches) = O Other: Length (inches) = Width (inches) _ Section 07 - Control Device Information O Vapor Recovery Unit (VRU) used for control of the Storage Tank(s) O Combustion Device used for control of the Storage Tank(s) Rating: MMBtu/hr Size: Make. Model: Type: Make Model Requested VOC & HAP Control Efficiency: % VOC & HAP Control Efficiency: Requested: % Manufacturer Guaranteed: % Annual time that VRU is bypassed (emissions vented): % Minimum temp. to achieve requested control: °F Waste gas heat content: Btusef O Closed loop system used for control of the storage tank(s) Constant pilot light? ❑ Yes O No Pilot burner rating: MMBtuhr Description: O Describe Any Other: Section 08 — Gas/Liquids Separation Technology Information (E&P Sites Only) What is the pressure of the final separator vessel prior to discharge to the storage tank(s)? psig Please describe the separation process between the well and the storage tanks: Section 09 — Emissions Inventory Information & Emission Control Information El Emission Factor Documentation attached Data year for actual calendar yr. emissions below & throughput in Sec. 04 (e.g. 2007): ' Emission Factor Actual Calendar Year Emission Requested Permitted Emissions Estimation Method or Pollutant Uncontrolled Controlled Uncontrolled Controlled Emission Factor Uncontrolled Basis Units Source(Tons/Year) (Tons/Year) (Tons/Year) (Tons/Year) NOx VOC 3.56E-04 lb/bbl 1.30 EPA Tanks CO Benzene De minimis EPA Tanks Toluene De minimis EPA Tanks Ethylbenzene De minimis EPA Tanks Xylenes De minimis EPA Tanks n-Hexane 5.42E-05 lb/bbl 0.20 EPA Tanks 2,2,4-Trimethylpentane Please use the APCD Non-Criteria Reportable Air Pollutant Addendum form to report pollutants not listed above. Sectio 10 — militant Certificati certify that all information contained herein and information submitted with this application is complete, true and correct. /0 —3 / — f 'f Josh Patterson VP of Operations Sign e o Pers Legally Auth zed to Supply Data Date Name of Legally Authorized Person (Please print) Title u will be charged an additional APEN fee if the APEN is filled out incorrectly or is missing information and needs re-submittal. 2 Annual emissions fees will be based on actual emissions reported here. If left blank, annual emissions fees will be based on requested emissions. Additional Information Attach produced water laboratory analysis,stack test results and associated emissions calculations if you are 0 Check box to request copy of draft permit prior to issuance. Required: ® requesting a site specific emissions factor according to the guidance in PS Memo 14-03 El Check box to request copy of draft permit prior to public notice. FORM APCD-207 Page 2 of 2 CS SandOilRemovalTanks_AP_Fonn-APCD-207-ProducedWaterTank-APEN 20141020.doc AIR POLLUTANT EMISSION NOTICE (APEN) & Application for Construction Permit — Produced Water Storage Tank(s)' Permit Number: GP05 [Leave blank unless APCD has already assigned a permit Is & AIRS ID] Emission Source AIRS ID: / / Facility Equipment ID: Produced Water Unloading Sump [Provide Facility Equipment ID to identify how this equipment is referenced within your organization.) Section 01 — Administrative Information Section 02 — Requested Action (Check applicable request boxes) Company Name: NGL Water Solutions DJ, LLC NAILS, or O Request for NEW INDIVIDUAL permit ® SIC Code: Request for coverage under GENERAL PERMIT Source Name: Produced Water Unloading Sump 0 GP05 ❑ GP08 Source Location: C5 Salt Water Disposal Facility County: Weld O Request MODIFICATION to existing INDIVIDUAL permit (check boxes below) SW '/ SW % SECTION 29, T2N, R64W Elevation: 4951 Feet ❑ Change process or equipment O Change company name Mailing Address: 8207 West 20ih Street, Suite B ZIP Code: 80634 O Change pennit limit O Transfer of ownership O Other Greeley, CO O APEN Submittal for Permit Exempt/Grandfathered source Person To Contact: Josh Patterson Phone Number: 970-356-5560 O APEN Submittal for update only (Please note blank APEN's will not be accepted) E-mail Address: jpatterson@highsierraenergy.com Fax Number: 970-356-5563 Addl. Info. & Notes: Section 03 — General Information For existing sources, operation began on: / / For new or reconstructed sources, the projected startup date is: / / 2014 This Storage Tank is Exploration & Production Midstream or Downstream hours/ days weeks/ Located at: ❑ (E&P) ® Normal H f S Oi day 7 52 year Site week Will this equipment be operated in any NAAQS nonattainment area? 0 Yes ❑ No Are Flash Emissions anticipated at these tanks ❑ Yes ® No ► Are these produced water tanks located at a commercial facility that accepts oil production wastewater for processing? ® Yes O No I. Do these storage tanks contain less than I% by volume crude oil on an annual average basis? O Yes 0 No ► Are these produced water tanks subject to Colorado Oil and Gas Conservation Commission (COGCC) 805 series rules? If so, submit Form APCD-105. O Yes ® No ► Are you requesting _ 6 ton/yr VOC emissions. or are uncontrolled actual emissions _ 6 ton/yr? O Yes 0 No General description of equipment purpose: Produced Water Unloading Sump: 10' x 10' x 11' Section 04 — Storage Tank(s) Information Colorado Department of Public Health and Environment Air Pollution Control Division (APCD)This notice is valid for five Produced Water Requested Permit Limit: 7,300,000 bbl/year (5) years. Submit a revised APEN prior to expiration of five-year Throughput: Actual: bbl/year Actual While Controls Operational: bbl/year tenn, or when a significant change is made (increase production, new Tank Design: Fixed Roof: 0 Internal Floating Roof: O External Floating Roof: O equipment, change in fuel type, etc). Storage # of Liquid Manifold Installation Date of most recent Mail this form along with a check for 5152.90 per APEN for non- Tank Storage Vessels in Total Volume of storage vessel in storage tank Date Of First Production E&P, midstream and downstream sources or $152.90 for up to ID Storage Tank Storage Tank (bbl) (Month/Year) (Month/Year) five (5) APENs for E&P sources and $250 for each general permit registration to: SUMP 1 196 Colorado Department of Public Health & Environment APCD-SS-BI 4300 Cherry Creek Drive South Denver, CO 80246-1530 Wells Serviced by this Storage Tank or Tank Battery (E&P Sites Only) For guidance on how to complete this APEN form: API Number Name of Well Newly Reported Well Air Pollution Control Division: (303) 692-3150 - - ❑ Small Business Assistance Program (SBAP): (303) 692-3148 or - - O (303) 692-3175 APEN forms: http www.colorado.got cdphe oilgasAPENS - - 0 0 Application status: http w nv.colorado.am cdphe permitstatus FORM A PCD-207 Page 1 of 2 C5 Sump_AP_Form-APCD-207-ProducedWaterTank-APEN 20141020.doc AIR POLLUTANT EMISSION NOTICE (APEN) & Application for Construction Permit — Produced Water Storage Tank(s)' Permit Number: GP05 Emission Source AIRS ID: / / Section 05 — Stack Information (For Midstream sites only) Section 06 —Stack (Source, if no combustion) Location (Datum & either Lat/Long or UTM) Operator Stack Base Stack Discharge GP Horizontal Datum UTM UTM Easting or 11TM Northing or Method of Collection for Stack Elevation Height Above Temp. Flow Rate Velocity Moisture Ground Level (°F) (ACFM) (ft/sec) (°/,) (NAD27,NAD83, Zone Longitude Latitude Location Data (e.g.map, ID No. (feet) (feet) WGS84) (12 or 13) (meters or degrees) (meters or degrees) GPS GoogleEarth) SUMP 4951 WGS84 13 535586.08 (m) 4439394.76 (m) GoogleEarth Direction of stack outlet (check one): O Vertical O Vertical with obstructing raincap O Horizontal O Down O Other (Describe): Exhaust Opening Shape & Size (check one): ❑ Circular: Inner Diameter(inches) = O Other: Length (inches) = Width (inches) = Section 07 — Control Device Information O Vapor Recovery Unit (VRU) used for control of the Storage Tank(s) O Combustion Device used for control of the Storage Tank(s) Rating: MMBtu/hr Size: Make'Model: Type: Make/Model Requested VOC & HAP Control Efficiency: % VOC & HAP Control Efficiency: Requested: % Manufacturer Guaranteed: Annual time that VRU is bypassed (emissions vented): % Minimum temp. to achieve requested control: °F Waste gas heat content: Btu'scf O Closed loop system used for control of the storage tank(s) Constant pilot light? O Yes O No Pilot burner rating: MMBtu/hr Description: O Describe Any Other: Section 08 — Gas/Liquids Separation Technoloay Information (E&P Sites Only) What is the pressure of the final separator vessel prior to discharge to the storage tank(s)? psig Please describe the separation process between the well and the storage tanks: Section 09 — Emissions Inventory Information & Emission Control Information 0 Emission Factor Documentation attached Data year for actual calendar yr. emissions below & throughput in Sec. 04 (e.g. 2007): 1 Emission Factor Actual Calendar Year Emission Requested Permitted Emissions Estimation Method or Pollutant Uncontrolled Controlled Uncontrolled Controlled Emission Factor Uncontrolled Basis Units (Tons/Year) (Tons/Year) (Tons/Year) (Tons/Year) Source NOx VOC 3.34E-04 lb/bbl 1.22 EPA Tanks CO Benzene De minimis EPA Tanks Toluene _ De minimis EPA Tanks Ethylbenzene De minimis EPA Tanks Xylenes De minimis EPA Tanks n-Hexane 5.08E-05 lb/bbl 0.19 EPA Tanks 2,2,4-Trimethylpentane Please use the APCD Non-Criteria Reportable Air Pollutant Addendum form to report pollutants not listed above. _ Section 1 lj Applicant Certifi - he eby certify that all information contained herein and information submitted with this application is complete, true and correct. i /0 —3/ c -"14 Josh Patterson VP of Operations Sig a, re of Person Legally A orized to Supply Data Date Name of Legally Authorized Person (Please print) Title ou will be charged an additional APEN fee if the APEN is filled out incorrectly or is missing information and needs re-submittal. r Annual emissions fees will be based on actual emissions reported here. If left blank, annual emissions fees will be based on requested emissions. Additional Information Attach produced water laboratory analysis. stack test results and associated emissions calculations if you are Ei Check box to request copy of draft permit prior to issuance. Required: ® requesting a site specific emissions factor according to the guidance in PS Memo 14-03 0 Check box to request copy of draft permit prior to public notice. FORM A PCD-207 Page 2 of 2 C5 Sump_AP_Form-APCD-207-ProducedWaterTank-APEN 20141020.doc AIR POLLUTANT EMISSION NOTICE (APEN) & Application for Construction Permit — Hydrocarbon Liquid Loading' Please use the Fuel Dispensing Station APEN to report emissions from service stations and fleet refueling stations Permit Number: [Leave blank unless APCD has already assigned a permit#& AIRS ID] Emission Source AIRS ID: / / Facility Equipment ID: L-1 [Provide Facility Equipment ID to identify how this equipment is referenced within your organization.] Section 01 — Administrative Information Section 02 — Requested Action (Check applicable request boxes) Company Name: NGL Water Solutions, LLC Action Applies To: n Individual Permit n General Permit GP07 Source Name: L-1 NAICS, or 0Request NEW permit or newly reported emission source Source Location: n SIC Code: Request REGISTRATION for coverage under GP07 & concurrent C5 Salt Water Disposal Facility request for CANCELLATION of individual permit number: SW 1/4 SW 1/4 SECTION 29, T2N, R64W n Request MODIFICATION to existing permit (check each box below that applies) Mailing Address: 8207 West 20th Street, Suite B County: Weld n Change process or equipment n Change company name Greeley, CO Elevation: 4951 Feet 11 Changepermit limit g ❑ Transfer of ownership 0 Other Person To Contact: Josh Patterson ZIP Code: 80634 n Request to limit HAPs with a Federally enforceable limit on PTE E-mail Address: n Request APEN update only. Note— Emissions data must be completed. Blank APENs jatterson@highsierraenergy.com will not be accepted Phone Number: 970-356-5560 Fax Number: 970-356-5563 Addl. Info. & Notes: Section 03 — General Information Date operation began or projected startup date: / / 2014 Normal Hours of Source Operation: 24 hottrs/day 7 days..wcek 52 weeks.'year General description of equipment and purpose: Oil Loadout ► Is this source located at an oil and gas exploration and production site? ❑ Yes El No 0 Don't know If yes, does this source load less than 10,000 gallons of crude oil per day on an annual average, splash fill less than 6750 BBL of condensate per year 0 No or submerge fill less than 16,308 BBL of condensate per year? r—, Yes ❑ Don't know D. Is this source located at a facility that is considered a Major Source of Hazardous Air Pollutant (HAP) emissions? 0 Yes" 0 No 0 Don't know D. Will this equipment be operated in any NAAQS nonattainment area? (www.colorado.Ros.'cdphe.'ozone) ❑ Yes" 0 No 0 Don't know D. Does this source load gasoline into transport vehicles? ❑ Yes" El No 0 Don't know ' If"Yes", provide an applicability determination of state and federal rules. Colorado Department of Public Health and Environment Section 04 — Loading Information Air Pollution Control Division (APCDI Product Loaded: fl Condensate n Crude Oil Other: P. If this APEN is being filed for vapors displaced from cargo carrier, complete the following: This notice is valid for five (5) years. Submit a revised APEN prior to expiration of five-year term, or when a significant change is made Annual Volume Loaded: Requested2: 219,000 bbl/year Actual calendar year: bbl/year (increase production, new equipment, change in fuel type, etc). This product is loaded from tanks at this facility into: Tank Trucks (e.g, "rail tank cars," or "tank trucks") Mail this form along with a check for 81.52.90 per APEN & • If site-specific emission factor is used to calculate emissions (Not available for GP07), complete the following: S250.00 for each general permit registration to: Saturation Factor'': 0.6 Average Temperature of Bulk Liquid Loaded: 60 °F Colorado Department of Public Health & Environment True Vapor Pressure: 2.8 psia @ 60 °F Molecular Weight of Displaced Vapors: 50 Lb/lb-mot APCD-SS-B1 10. If this APEN is being filed for vapor losses from pressurized loading lines, complete the following: 4300 Cherry Creek Drive South Loads peryear: Requested2: #.'yr•. Actual Calendar Year: #/y1•. Product Density: Lb/ft' Denver, CO 80246-1530 Load Line Volume4: Ft'/truckload Vapor Recovery Line Volume: FtVtruckload For guidance on how to complete this APEN form: 1 You may be charged an additional APEN fee for APEN re-submittal due to incorrectly filled-out APEN or missing information. Air Pollution Control Division: (303)692-3150 2 Requested values will become permit limitations for individual construction permits. Small Business Assistance Program (SBAP): (303) 692-3148 or 3 Please refer to AP-42,Table 5.2-I for information on saturation factors(found online at: hnp NI we.rna.goshtnlchief/aMLcho5li nth:c.htmn. (303) 692-3175 ' List the total volume for all lines in each category and attach your calculations of these volumes. APEN forms: www.colorado.J,*o► 'cdphe."alrforms FORM APCD-208 Permit status: www.colorado.got 'cdphe/permitstatus Page 1 of 2 FormAPCD-208-HydrocarbonLiquidLoadingAPEN-Ver.4-14-2014 (I).docx AIR POLLUTANT EMISSION NOTICE (APEN) & Application for Construction Permit — Hydrocarbon Liquid Loadings Please use the Fuel Dispensing Station APEN to report emissions from service stations and fleet refueling stations Permit Number: Emission Source AIRS ID: / / Section 05 - Stack Information (Combustion stacks must be listed here) Section 06 —Stack (Source, if no combustion) Location (Datum & either Lat/Long or UTM) Stack Discharge Operator Stack Base Honzontal Datum UTM UTM Easung or UTM Northing or Method of Collection for Stack Elevation Height Above Temp. Flow Rate Velocity Moisture Ground Level (°F) (ACFM) (f /see) (°/,) (NAD27, NAD83, Zone Longitude Latitude Location Data (e.g. map, ID No. (feet) (feet) WGS84) (12 or 13) (meters or degrees) (meters or degrees) GPS, GoogleEarth) L-1 4951 WGS84 13 535586.08 (m) 4439394.76 (m) GoogleEarth Direction of stack outlet (check one): I I Vertical n Vertical with obstructing raincap n Horizontal n Down n Other (Describe): Exhaust Opening Shape & Size (check one): n Circular: Inner Diameter(inches) = n Other: Length (inches) = Width (inches) = Section 07 — Control Device Information ❑ Loading occurs using a vapor balance system. O Combustion Device used for control of the loadout emissions. Rating: MMBtu/hr ❑ Describe Any Other (Including VRLI) Type: Make Model/Serial ti: V0C & HAP Control Efficiency: Requested: °lo Manufacturer Guaranteed: 04 Minimum temp. to achieve requested control: °F Waste gas heat content. Btu/scf V0C & HAP Control Efficiency: Requested: % Constant pilot light? n Yes ❑ No Pilot burner rating: MMBtu/hr Section 08 — Emissions Inventory Information _n State Emission Factors (Required for general permit GP07 - Optional for individual permit) T1 Condensate VOC: 0.236 Lbs/BBL Benzene: 0.00041 Lbs/BBL n-Hexane: 0.0036 Lbs/BBL n Crude Oil VOC: 0.104 Lbs/BBL Benzene: 0.00018 Lbs/BBL n-Hexane: 0.0016 Lbs/BBL n Emission Factor Documentation attached (If using site specific emission factor) Data year for actual calendar year emissions below & throughput in Sec. 04 (e.g. 2007): Control Device Description Emission Factor Actual Calendar Year Emissronss Requested Permitted Estimation Pollutant Control Efficiency Emissions Method or (% Reduction) Uncontrolled Controlled Uncontrolled Controlled Emission Pnmary Secondary Uncontrolled Basis Units (Tons/Year) (Tons/Year Tons/Year) . ( ) , (Tons'Year) Factor Source N0x V0C 2.01 lb/1000 gal 9.26 AP42 CO Identify in Section 07 Benzene 0.039 lb/1000 gal 0.18 AP42 n-Hexane 0.306 lb/1000 gal 1 .41 AP42 Please use the APCD Non-Criteria Reportable Air Pollutant Addendum form to report pollutants not listed above. You may be charged an additional APEN fee for APEN re-submittal due to incorrectly filled-out APEN or missing information. `Annual emission fees will be based on actual emissions reported here. n Check box to request copy of draft permit prior to issuance. Section 09—Applicant Certification - I hereby certify that all information contained herein and information submitted with this application is complete, true and correct. If this is a registration for coy rage f der general permit GP07 t e certify that this source is and will be)) operated in full compliance with each condition of general permit GP07.10 —3/ "/if' Josh Patterson VP of Operations Si: a e of Person Legally Autho • e to Supply Data Date Name of Legally Authorized Person (Please print) Title Page 2 of 2 FormAPCD-208-HydrocarbonLiquidLoadingAPEN-Ver.4-14-2014 (I).docx NON-CRITERIA REPORTABLE AIR POLLUTANT EMISSION NOTICE ADDENDUM (See reverse side for guidance on completing this form) Permit Number AIRS ID Number: Company Name: NGL Water Solutions, LLC Plant Location: C5 Salt Water Disposal Facility - SW 1/4 SW 1/4 SECTION 29, T2N, R64W County: Weld Zip Code: 80634 Person to Contact: Josh Patterson Phone Number: 970-356-5560 E-mail Address: jatterson@highsierraenergy.com Fax Number: 970-356-5563 Chemical Abstract Control Equipment Emission Factor Emission Factor Uncontrolled Controlled Actual Service (CAS) Chemical Name / Reduction (%) Actual Emissions Emissions Number (Include Units) Source (lbs/year; (Ibs/year; 108-88-3 Toluene NA 0.068 lb/1000 gal AP42 626.57 NA Ca nd Year for which Actual t Applies: Si ature of Person Legally Authorized to Supply Data ` e —3/ ` �� 9 Y pp Y Date Josh Patterson VP of Operations Name of Person Legally Authorized to Supply Data (Please print) Title of Person Legally Authorized to Supply Data Form Revision Date: April 14, 2014 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. I ) 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 Sections 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 (471bbl) 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 m3 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 0000 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. 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 D Facility Emission Calculations and Supporting Documentation NGL Water Solutions DJ, LLC Facility: C5 Salt Water Disposal Facility TANK EMISSIONS Facility Throughput 20,000 bbl/day 7.300.000 bbl/yr Total Volume Vol/WI%• Vol/Wt%• Oil Water Throughput Tank ID Tank Description Permit#/AIRS IDs Installation Date gaUyr Oil Water gal/yr gal/yr ti of Tanks gal/yr/tank P1 Desand Tanks(2 x 700 bbl) APEN Pending TBD 308,800.000 3.00"0 97.00°. 9.108,000 297,402.000 2 153,300.000.00 P2 Sand and Oil Removal Tanks(2 x 1000 bbl) APEN Pending TBD 306,000,000 3.00°.. 97.00% 9.108,000 297.402.000 2 153.300,000.00 P4 Oil Heating Tank(1 x 400 bbl) APEN Pending TBD 9,198.000 100.00% 0.00% 9.198,000 0 1 9.108,000.00 T1 Water Equalization Tanks(8 x 840 bbl) APEN Exempt TBD 297,402.000 0.1O'r 99.90% 297.402 297,104,598 8 37.175.250.00 T2 Post-Filer Tanks(2 x 1000 bbl) APEN Exempt TBD 297,402,t 40 0.10% 99.90% 297.402 207,104,598 2 148.701,000.00 T3 Oil Tanks(3 x 400 bbl) APEN Pending TBD 9,198,000 100.00% 0.00' 9,198.000 0 3 3,006.000.00 T4 Slop Oil Tank(1 x 400 bbl) APEN Pending TBD 9.198,000 100.00% 0.00% 9,198,000 0 1 9,198,00000 T5 Sale Oil Tank(1x400bbl) APEN Pending TBD 9,198,000 100.0040 0.00% 9,108,000 0 1 9,198,000.00 'Because oil is less dense than water,it is conservatively assumed oil and water densities are equal and that volume%is equal to weight% The oil tanks(P4,T3,T4,T5)are assumed to have 100'4 oil Emissions VOC Benzene Toluene Ethylbenzene Xylenes n-Hoxane Methanol Emission Unit Emission Unit Permit ft/AIRS IDs ID/yr/lk I. lb/yr } TPY lb/yr lb/yr _ lb/yr lb/yr Ib/yr lb/yr P1 Desand Tanks(2 x 700 bbl) APEN Pending 1271 75 2543.50 1.27 48.81 86.08 2.10 32.40 387.22 0.00 P2 Sand and Oil Removal Tanks(2 x 1000 bbl) APEN Pending 1209.44 2598.88 1.30 49.87 87.96 2.15 33.11 395 05 0.00 P4 Oil Heating Tank(1 x 400 bbl) APEN Pending 3635.4D 3835.40 1.82 70.08 140.18 0.00 61.32 551.88 0.00 T1 Water Equalization Tanks(8 x 840 bbl) APEN Exempt 12.02 98.10 0.05 1 85 3.25 0.08 1.23 14.84 0.00 T2 Post-Filter Tanks(2 x 1000 bbl) APEN Exempt 41.13 82.28 0.04 1.58 2.78 0.07 1.05 12.52 0.00 T3 Oil Tanks(3 x 400 bbl) APEN Pending 1401.60 4204.80 2 10 78.84 131.40 0.00 52.58 657.00 0.00 T4 Slop Oil Tank(1 x 400 bbl) APEN Pending 2444.04 2444 04 1.22 43.80 87.80 0.00 35.04 376.68 0.00 T5 Sale Oil Tank(1 x 400 bbl) APEN Pending _ 2444.04 2444.04 1.22 43.80 87.80 0.00 35.04 376.08 0.00 Conversion from Vol/W to Mol% Composite VP Calculation RAPS Speciation• MW Mot% Ad).MW Wt%• Max True Vapor Press. Analyze Mass% 3%oil/97%v.ater Ibfb•rnol Ib/lb-mol psia kPa Benzene 1.92'0 Gasoline(RVP10) 92 0.60% 0.55 3.0% 5.00 34.50 Toluene 3.38% Water 18.02 09.40% 17.91 97.0% 0.40 2.76 Ethylbenzene 0.08% Composite Liquid 18.47 0.428 2.95 Xylenes 1.27% VOL contribution 0.03 0.21 n-Hexane 15.22% Methanol 0.00`, Mr'/ Mol% Adj. MW Wt%' Max True Vapor Press •Sp*,41.n horn ESP Tank Results O.1%Oil/09.9%water Ib/lb-mot lb/lb-mot psia kPa Gasoline(RVP10) 92 0.02% 0.02 0.1% 5.00 34.50 Water 18.02 99.08% 18 02 99.9"5 0.40 2.78 Composite Liquid 18.03 0.401 2.78 VOL contribution 0.00 0.01 'Because of is less dense Iran rate .l s consave ely ass:anti♦d oil end waist de....oes ere equal I..d Mal volume it 0001010 weget•'r Notes: For the PW tanks,the oil portion was modeled using Gasoline(RVP10)in TANKS 4.09d.All water sent to this facility will be trucked in post-flash from production facilities and may include crude oil or condensate. However,it is expected the more volatile compounds wit flash off at the source facilities and therefore.Gasoline(R"P10)is a conservative representation of the oilbvater mix trucked in on site.Liquid analysis value= RVP 3.2.API gravity=47 consistent-•pith condensate per Colorado definition TANKS 4.0 Report Page 1 of 5 TANKS 4.0.9d Emissions Report - Summary Format Tank Indentification and Physical Characteristics Identification User Identification: C5 700 bbl Desanding Tank (P1) City: Denver State: Colorado Company: NGL Water Solutions DJ, LLC Type of Tank: Vertical Fixed Roof Tank Description: 2 x 700 bbl Desanding Tanks (3% oil by volume) Modeled for one tank. Tank Dimensions Shell Height (ft): 35.00 Diameter (ft): 12.00 Liquid Height (ft) : 35.00 Avg. Liquid Height (ft): 17.50 Volume (gallons): 29,611.04 Turnovers: 5.177.12 Net Throughput(gal/yr): 153,300,000.00 Is Tank Heated (y/n): N Paint Characteristics Shell Color/Shade: Gray/Light Shell Condition Good Roof Color/Shade: GraylLight Roof Condition: Good Roof Characteristics Type: Cone Height (ft) 0.00 Slope (ft/ft) (Cone Roof) 0.06 Breather Vent Settings Vacuum Settings (psig): -0.03 Pressure Settings (psig) 0.03 Melerological Data used in Emissions Calculations: Denver, Colorado (Avg Atmospheric Pressure = 12.12 psia) Iile:///C:/Prograni%20Files%20(x86)/Tanks409d/summaiydisplay m m 10/13/2014 TANKS 4.0 Report Page 2 of 5 TANKS 4.0.9d Emissions Report - Summary Format Liquid Contents of Storage Tank C5 700 bbl Desanding Tank (P1) - Vertical Fixed Roof Tank Denver, Colorado Liquid OP.y!Atrial Surf Buft Vapor Ltqu4 Vapor Tompe•atare(dog F) Temp Vapor Pressure(Ps 4) Mot Mass Mass Mot Basis for Vapor Pressure Medure/Cornpcnent Month A,.:; M Max (deg F) Avg Mn M-x Wright react Frad Woght Cale.Mt:0ns Produced Water A 5816 47 20 8912 G?45 0 2584 01833 0-873 23 4046 18 47 Gas 10(RVP 10) 5 0\032 4 0235 ri 1698 66 .3y0 0 C303 0 3165 92 00 Optwn 4 RVP=.1• ASTM S'ope=3 Water 02398 01'. D:v.. ' 16. 100 09700 06835 t-sr Option A=8 10715 8=1750 2tr, C=235 file:///C:/Program%20Files%20(x86)/Tanks409d/summarydisplay.htm 10/13/2014 TANKS 4.0 Report Page 4 of 5 TANKS 4.0.9d Emissions Report - Summary Format Individual Tank Emission Totals Emissions Report for: Annual CS 700 bbl Desanding Tank (P1) - Vertical Fixed Roof Tank Denver, Colorado 1 Losses(Ibs) Components Working Loss Breathing Loss Total Emissions Produced Water J 3,954.88 63.66 r 4,018.55 Gasoline (RVP 10) 1 1,251.60 20.15 1,271.75 Water L—_ 2703.28 43.51' 2,746.79 file:///C:/Program%20l:iles%20(x86)/I'anks409d/summarydisplay.htm 10/13/2014 TANKS 4.0 Report Page 1 of 5 TANKS 4.0,9d Emissions Report - Summary Format Tank indentification and Physical Characteristics Identification User Identification: C5 1000 bbl Sand and Oil Removal Tank (P2) City: Denver State: Colorado Company: NGL Water Solutions DJ, LLC Type of Tank: Vertical Fixed Roof Tank Description: 2 x 1000 bbl Sand and Oil Removal Tank (3% oil by volume) Modeled for one tank. Tank Dimensions Shell Height (ft): 30.00 Diameter(ft): 15.50 Liquid Height (ft) : 30.00 Avg. Liquid Height (ft): 15.00 Volume (gallons): 42,345.55 Turnovers: 3,620.22 Net Throughput(gal/yr): 153,300,000.00 Is Tank Heated (y/n): N Paint Characteristics Shell Color/Shade: Gray/Light Shell Condition Good Roof Color/Shade: Gray/Light Roof Condition: Good Roof Characteristics Type: Cone Height (ft) 0.00 Slope (ft/ft) (Cone Roof) 0.06 Breather Vent Settings Vacuum Settings (psig): -0.03 Pressure Settings (psig) 0.03 Meterological Data used in Emissions Calculations: Denver, Colorado (Avg Atmospheric Pressure = 12.12 ps:a) file:///C:/Program%20Files%20(x86)/Tanks409d/summarydisplay.htm 10/13/2014 TANKS 4.0 Report Page 2 of 5 TANKS 4.0.9d Emissions Report - Summary Format Liquid Contents of Storage Tank C5 1000 bbl Sand and Oil Removal Tank (P2) - Vertical Fixed Roof Tank Denver, Colorado L'qr,d Da y Lpu.d Surf 13U"{ Vapor LiaLrd Vapor Temperature(dog F) Temp Vapor Pressure(ps.a) Mot Mass Mass td1:.: 8a_ s for Vapor Pressure Mixture/Cate:. en! Month Avg M r Max (deg F) Avg M n Max Weight Fract Frac( Waight Cat a1xns Produced Wa:er Al 5916 47 20 6912 52 45 0 2684 0 1833 0 3873 23 4045 18 47 Gasohne(RVP 101 5 0032 4 02C 6 1698 65 0f/10 00300 0 3165 9.:00 ()pica 4 RVP='0,ASTM S ope=3 Water 02...• 01601 03522 18020 09700 C 5835 1802 Orlon A=8107(5 8=1750286 C=235 file:///C:/Program%20Fi1es%20(x86)/Tanks409d/summarydisplay.htm 10/13/2014 TANKS 4,0 Report Page 4 of 5 TANKS 4.0.9d Emissions Report - Summary Format Individual Tank Emission Totals Emissions Report for: Annual CS 1000 bbl Sand and Oil Removal Tank (P2) - Vertical Fixed Roof Tank Denver, Colorado Losses(lbs) Components Working Loss Breathing Loss Total Emissions Produced Water 4,012.03 94.00 4,106.03 i Gasoline (RVP 10) 1,269.69 29.75 1,299.44 Water j 2,742.34 64.25 2,806.60 file:///C:/Program%20Files%20(x$6)/Tanks409d/summaiydisplay.ltim 10/13/2014 E&P TANK V2 . 0 Calculation Report--- Developed by DB Robinson & Associates Ltd. 2014 . 10 . 13 ****************************, ************************************************************* * Project Setup Information * ****************************************************************************************** Project File : C : \Users\Melissa Olson\Desktop\C5 Application Files 20141013\TANKS Runs and Model : Stable Oil Tank Calculation Method : AP42 Control Efficiency : 100 . 0% Filed Name : C5 Oil Heat Tank (1 x 400 bbl) . Modeled for one tank Well Name : C5 Date : 2014 . 10 . 13 ****************************************************************************************** * Data Input * ****************************************************************************************** Separator Pressure : 23 . 00 [psig] Separator Temperature : 85 . 00 [F] Ambient Pressure : 14 . 70 (psia] Ambient Temperature : 70 . 00 [F] CI0+ 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 . 13 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 * ***************************************************************************** ************* -- Fm4ssion Summary Item Uncontrolled Uncontrolled [ton/yr] [lb/hr] Total RAPs 0 . 410 0 . 094 Total EC 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 02 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 CS 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 rimissions 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 . 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 . 13 15 C9 128 . 28 5 . 5127 14 . 9211 3 . 5889 16 CIO+ 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 . @ 100Fjpsia] 1 . 48 1 . 48 RVP @ 100F [psia] 10 . 09 10 . 09 SG @ 100F 0 . 807 0 . 807 page 3 TANKS 4.0.9d Emissions Report - Summary Format Tank Indentification and Physical Characteristics Identification User Identification: C5 840 bbl Water Equalization Tank(T1) City: Denver State: Colorado Company: NGL Water Solutions DJ, LLC Type of Tank: Vertical Fixed Roof Tank Description: 8 x 840 bbl Oil Removal Tank(0.11:10 oil by volume) Modeled for one tank Tank Dimensions Shell Height (ft): 25.00 Diameter (ft): 15.50 Liquid Height (ft) : 25.00 Avg. Liquid Height (ft): 12.50 Volume (gallons): 35,287.95 Turnovers: 1,053.48 Net Throughput(gal/yr): 37,175,250.00 Is Tank Heated (y/n): N Paint Characteristics Shell Color/Shade: Gray/Light Shell Condition Good Roof Color/Shade: Gray/Light Roof Condition: Good Roof Characteristics Type: Cone Height (ft) 0.00 Slope (ft/ft) (Cone Roof) 0.06 Breather Vent Settings Vacuum Settings (psig): -0,03 Pressure Settings (psig) 0.03 Meterological Data used in Emissions Calculations: Denver. Colorado (Avg Atmospheric Pressure = 12.12 psia) TANKS 4.0.9d Emissions Report - Summary Format Liquid Contents of Storage Tank C5 840 bbl Water Equalization Tank (T1) - Vertical Fixed Roof Tank Denver, Colorado Liquid Daily Liquid Surf. Bulk Vapor Liquid Vapor Ternpewvre(deg F) Temp Vapor Pressure(psia) Mol, Mass Mass Mel. Basis for Vapor Prossure Mixture/Component Month Avg, Min. Max. (deg F) Avg. Min, Max. Weight Fact. Frost Weight Cakulations Produced Water All 58.16 4720 69.12 52.45 02407 0.1808 0.3534 182155 18.03 Gasoline(RVP 10) 5.0032 4.0205 6.1698 66.0000 0.0010 0.0148 92.00 Option 4.RVP=10.ASTM Slope=3 Water 02398 0.1601 0.3522 18.0200 0.9990 0.9852 18.02 Option 2'A=8.10765.9=1750.286,C=235 TANKS 4.0.9d Emissions Report - Summary Format Individual Tank Emission Totals Emissions Report for: Annual C5 840 bbl Water Equalization Tank (11) - Vertical Fixed Roof Tank Denver, Colorado Losses(Ibs) Components Working Loss Breathing Loss Total Emissions Produced Water 757.29 56.75j 814.04 Gasoline (RVP 10) 11.18 0.84 12.02 Water 7.46.11 55.91 802.02 TANKS 4.0.9d Emissions Report - Summary Format Tank Indentification and Physical Characteristics Identification User Identification: C5 1000 bbl Post Filter Tank(T2) City: Denver State: Colorado Company: NGL Water Solutions DJ, LLC Type of Tank: Vertical Fixed Roof Tank Description: 2 x 1000 bbl Post Filter Tanks (0.1% oil by volume) Modeled for one tank Tank Dimensions Shell Height (ft): 30.00 Diameter (ft): 15.50 Liquid Height (ft) : 30.00 Avg. Liquid Height (ft): 15.00 Volume (gallons): 42,345.55 Turnovers: 3.511.61 Net Throughput(gal/yr): 148,701,000.00 Is Tank Heated (y/n): N Paint Characteristics Shell Color/Shade: Gray/Light Shell Condition Good Roof Color/Shade: Gray/Light Roof Condition: Good Roof Characteristics Type: Cone Height (ft) 0.00 Slope (fUft) (Cone Roof) 0.06 Breather Vent Settings Vacuum Settings (psig): -0.03 Pressure Settings (psig) 0.03 Meterological Data used in Emissions Calculations: Denver, Colorado (Avg Atmospheric Pressure = 12.12 psia) TANKS 4.0.9d Emissions Report - Summary Format Liquid Contents of Storage Tank C5 1000 bbl Post Filter Tank (T2) - Vertical Fixed Roof Tank Denver, Colorado Liquid Daily Liquid Stitt. Bulk Vapor Liquid Vapor Temperature(deg F) Tarp Vapor Pressure(psis) Mol. Mass Mass Mol. Basis for Vapor Pressure Mixture/Component Month Avg. Min. Max. (deg F) Avg. Mln. Max. Weight Fraet. Fract Weight Cakubbons Produced Water All 58.16 47.20 69.12 52.45 02407 0.1608 0.3534 18.2156 18.03 Gasoline(RVP 10) 5.0032 4.0205 6.1698 66.0000 00010 0.0148 92.00 Option 4 RVP=10.ASTM Slope=3 Water 02398 01601 0.3522 18.0200 0.9990 0.5652 18.02 Option 2.AS.10765,8=1750.286,C=235 TANKS 4.0.9d Emissions Report - Summary Format Individual Tank Emission Totals Emissions Report for: Annual C5 1000 bbl Post Filter Tank (T2) - Vertical Fixed Roof Tank Denver, Colorado Losses(Ibs) Components Working Loss Breathing Loss Total Emissions Produced Water 2,719.74 _ _ 66.14 2,785.88 Gasoline (RVP 10) 40.15 0,981 41.13 Water 2,679.581 65.16 2,744.75] E&P TANK V2 . 0 Calculation Report--- Developed by DB Robinson & Associates Ltd . 2014 . 10 . 13 *********************** ******************************************************************* * Project Setup Information * ****************************************************************************************** Project File : C : \Users\Melissa Olson\Desktop\C5 Application Files 20141013\TANKS Runs and Model : Stable Oil Tank Calculation Method : AP42 Control Efficiency : 100 . 0% Filed Name : C5 Oil Tank (3 x 400 bbl) . Modeled for one tank Well Name : C5 Date : 2014 . 10 . 13 ****************************************************************************************** * 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 : 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 E&P TANK V2 . 0 Calculation Report--- Developed by DB Robinson & Associates Ltd. 2014 . 10 . 13 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 * ****************************************************************************************** -- Rm4ssion Summary Item Uncontrolled Uncontrolled [ton/yr] [ib/hr] Total AAPs 0 . 160 0 . 037 Total AC 0 . 702 0 . 160 VOCs , C2+ 0 . 702 0 . 160 VOCs , C3+ 0 . 702 0 . 160 Uncontrolled Recovery Info . Vapor 16 . 6500 x1E-3 [MSCFD] AC Vapor 16 . 6500 x1E-3 [MSCFD] GOR 0 . 08 [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 . 076 0 . 017 11 n-05 0 . 060 0 . 014 12 C6 0 . 152 0 . 035 13 C7 0 . 183 0 . 042 14 C8 0 . 047 0 . 011 15 C9 0 . 027 0 . 006 16 C10+ 0 . 000 0 . 000 17 Benzene 0 . 014 0 . 003 18 Toluene 0 . 024 0 . 005 19 E-Benzene 0 . 001 0 . 000 20 Xylenes 0 . 009 0 . 002 21 n-C6 0 . 109 0 . 025 22 224Trimethylp 0 . 000 0 . 000 Total 0 . 702 0 . 160 -- 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 . 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 E&P TANK V2 . 0 Calculation Report--- Developed by DB Robinson & Associates Ltd. 2014 . 10 . 13 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 C 100F 0 . 807 0 . 807 page 3 &P TANK V2 . 0 Calculation Report--- Developed by DB Robinson & Associates Ltd. 2014 . 10 . 13 ************************************************************************************* ***** * Project Setup Information * ******* *******************************************************************************,t*** Project File : C : \Users\Melissa Olson\Desktop\C5 Application Files 20141013\TANKS Runs and Model Stable Oil Tank Calculation Method : AP42 Control Efficiency : 100 . 0% Filed Name : C5 Slop/Sale Oil Tanks (2 x 400 bbl) . Modeled for one tank Well Name : C5 Date : 2014 . 10 .13 ****************************************************************************************** * 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 02 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 224Txirnethylp 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 E&P TANK v2 . 0 Calculation Report--- Developed by DB Robinson & Associates Ltd. 2014 . 10 . 13 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/f t^2*day] *****************, ************************************************************************ * Calculation Results * ****************************************************************************************** -- Emission Summary Item Uncontrolled Uncontrolled [ton/yr] [lb/hr] Total HAPs 0 . 270 0 . 062 Total HC 1 . 220 0 . 279 VOCs , C2+ 1 .220 0 . 279 VOCs , C3+ 1 . 220 0 . 279 Uncontrolled Recovery Info . Vapor 28 . 9600 x1E-3 [MSCFD] HC Vapor 28 . 9600 xIE-3 [MSCFD] G0R 0 . 05 [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 . 133 0 . 030 11 n-05 0 . 105 0 . 024 12 C6 0 . 264 0 . 060 13 C7 0 . 318 0 . 073 14 C8 0 . 082 0 . 019 15 C9 0 . 047 0 . 011 16 C10+ 0 . 000 0 . 000 17 Benzene 0 . 024 0 . 005 18 Toluene 0 . 042 0 . 010 19 E-Benzene 0 . 001 0 . 000 20 Xylenes 0 . 016 0 . 004 21 n-C6 0 . 189 0 . 043 22 224Trimethylp 0 . 000 0 . 000 Total 1 . 221 0 . 279 -- 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 . 8292 13 . 2102 11 n-05 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 C8 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 . 13 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 RV?' @ 100F [psis] 10 . 09 10 . 09 SG @ 100F 0 . 807 0 . 807 page 3 Tank Dimensions Tank ID Tank Description # of Tanks Capacity (bbl) Diameter Height Vol (ft3) Vol (bbl) Vol (gal) Nom. Vol (gal) Water VoP/0 Oil Vol% P1 Desand Tanks 2 700 12 35 3958.41 712.51 29925.55 29,400 97 00% 3 00% P2 Sand and Oil Removal Tanks 2 1000 15.5 30 5660.76 1018.94 42795.32 42,000 97.00% 3.00% P4 Oil Heating Tank 1 400 12 20 2261.95 407.15 17100.32 16,800 5 00% 95.00% T1 Water Equalization Tanks 8 840 15.5 25 4717.30 849.11 35662.77 35,280 99 90% 0 10% T2 Post-Filter Tanks 2 1000 15 5 30 5660.76 1018.94 42795.32 42,000 99.90% 0 10% T3 Oil Tanks 3 400 12 20 2261.95 407.15 17100.32 16,800 5.00% 95 00% T4 Slop Oil Tank. 1 400 12 20 2261.95 407.15 17100.32 16,800 5.00% 95.00% T5 Sale Oil Tank 1 400 12 20 2261.95 407.15 17100.32 16,800 5.00% 95.00% SUMP Unloading Sump 11.28 11 1100.00 198.00 8316.00 8200 97.00% 3.00% NGL Water Solutions DJ , LLC Facility: C5 Salt Water Disposal Facility Permit #: 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 TANKS 4.0 Report Page 1 of 7 TANKS 4.O.9d Emissions Report - Detail Format Tank Indentification and Physical Characteristics Identification User Identification: C5 Produced Water Unloading Sump (Covered) City: Denver State: Colorado Company: NGL Water Solutions DJ, LLC Type of Tank: Vertical Fixed Roof Tank Description: Below ground covered concrete sump that is 10' x 10' x 11 deep Assumed to be a tank with an effective diameter of 11 28' and height of 11'for emisions modeling purposes. Tank Dimensions Shell Height (ft): 11.00 Diameter (ft): 11.28 Liquid Height (ft) : 11.00 Avg. Liquid Height (ft): 5.50 Volume (gallons): 8,223.07 Turnovers: 37,285.35 Net Throughput(gal/yr): 306,600,000.00 Is Tank Heated (y/n): N Paint Characteristics Shell Color/Shade: Gray/Light Shell Condition Good Roof Color/Shade: Gray/Light Roof Condition: Good Roof Characteristics Type: Cone Height (ft) 0.00 Slope (ft/ft) (Cone Roof) 0.06 Breather Vent Settings Vacuum Settings (psig): 0.00 Pressure Settings (psig) 0.00 Meterological Data used in Emissions Calculations: Denver, Colorado (Avg Atmospheric Pressure = 12 12 psia) file:///C:/Program%20Files%20(x8G)fianks409d/summarydisplay.htm 10/13/2014 TANKS 4.0 Report Page 2 of 7 TANKS 4.0.9d Emissions Report - Detail Format Liquid Contents of Storage Tank CS Produced Water Unloading Sump (Covered) - Vertical Fixed Roof Tank Denver, Colorado Liquid Da:y Lrqu:d S rf Bulk Vapor Liqu4 Vapor Temperer re(dog F) Temp Vapor Press:uc(Psat Mol Mass Mass MO Bass for Vap.. Pressure Mature/Component Mcr'h Avg M:n Max (dog F) Avg Mn Max We,gh1 Frect Frail Vderght Calcu!atr 3 Produced Water All 58 tri 47 20 63 12 52 45 0 2684 0 1833 0.7-3 23 4046 18 47 Gasotne(RVP 10) 5 00:" 4 02t. 6 1698 66 600O 0 060 0 3165 92 00 Option 4 RVP=10 ASTM S;opor3 Water 0235: 01cC1 03522 1802O0 09i0) Or 835 1802 Oplr 2 A'010765 Br17:0286 C=235 file:///C:/Program%20Files%20(x86)/fanks409d/surnmarydisplay.htm 10/13/2014 TANKS 4.0 Report Page 3 of 7 TANKS 4.0.9d Emissions Report - Detail Format Detail Calculations (AP-42) C5 Produced Water Unloading Sump (Covered) - Vertical Fixed Roof Tank Denver, Colorado An,• r,•Emission Casccu'ztx-ns Standing Losses (lb) 21 8505 Vapor Space Volume(cu ft) 561 3725 Vapor Density(Moroi It) 0 0011 Vapor Space Expansion Factor 01019 Vented Vapor Salvation Facto' 0 9250 Tan:Vapor Space Volume Vapor Space Vc .mo(cu ft) 551 3725 Tank Diameter(ft) 112900 Vapor Space Outage(1,) 5 6175 Tank Shell Ho:gh%(ft) 11 0003 Average Liquid He<ght(ft) 5 5000 Roof Outage(It) 0 1175 Roof Outage(Cone Roof) Roof Outago(ft) 01175 Roof Height (ft) 0 0000 Rcaf Slope OM) 0 C-.25 ': .oil Rad us(11 5 6400 Vapor Density Vapor Density(Ebtcu ft) 0 0011 Vapor Metcuter Wo;ght(lb/I:natio) 23 40.3 Vapor Pressure at Daty Averags Liquid Surface Temps alure(ps•a) 02(14 Da'y Avg Liquid Surface Temp (dog R) 517 8285 Da'y Average Ambient Temp (dog F) 50 2125 Ideal Gas Consta-1 R (psis cult l(lb-r f.I-dog R)) 10 731 Liquid Busk Temper:lure(dog R) 512 1225 Tank Pant Solar Absorptci co(Sho:I) 05400 Tank Part Soler Absorptance(Root) 0 54-1 Davy Total Solar In utat•on Factor(Btursgft day) 1 Su 5833 Vapor Space Expansion Factor Vapor Space Expansion Factor 01019 Daily Vapor Temperature Range(deg R) 43 8350 Daly Vapor Pressure Range(ps;a) 02039 Breather Vent Press Setting Range(psa) 0 0000 Vapor Pressure at Daily Average Liquid Surface Temperaturo(ps:a) 0 2584 Vapor Pressure at Daly Mnimum Lulu Surface Temperature(psa) 0 11333 Vapor Pressure at Daly Maximum I.iquid Strface Temperature(ps:a) 0 3873 Daily Avg Liquid Surfaco Temp (dog R) 517 8285 Da.'y Min Liquid Surface Temp (dog R) 506 8697 Daily Max Liquid Surface Tamp (dog R) 528 7872 Daly Ambient Temp Range(dog R) 27 9417 Vented Vapor Saturation Factor Vented Vapor Sataation Factor D 9260 Vapor Pressure at Day Average Liquid Surface Temperature(0513) 0 7084 Vapor Space Outage(ft) 5?175 file:///C:/Program%20Files%20(x86)/Tanks409d/summarydisplay.htm 10/13/2014 TANKS 4.0 Report Page 4 of 7 Working Losses(tb) 7 660 9019 Vapor Mc ocular Wa]ht(ib/lb mole) 23 4046 Vapor Pressure at Da Average Liquo Surface Temperature(psia) 02694 Annual Not Throughput(gaUyr) 30 r+AO 000 0030 Annual Turnovers 37 2F'3469 Turnover Fe or 01675 Maximum Liquid Vc!umo(g_) 8 223 LX35 Maxim .n Liqud Height('.t) 11 0000 Tank Diameter(ft) 1 t 28O0 %Marking Loss Product Fact' 1 0000 Total Losses(lb) 7 702 7/24 file:///C:/Program%20Piles%20(x86)/Tanks409d/summarydisplay.htm 10/13/2014 TANKS 4.0 Report Page 6 of 7 TANKS 4.0.9d Emissions Report - Detail Format Individual Tank Emission Totals Emissions Report for: Annual C5 Produced Water Unloading Sump (Covered) - Vertical Fixed Roof Tank Denver, Colorado Losses(Ibs) Components Working Loss Breathing Loss Total Emissions Produced Water 7,680.90 21.85 7,702.75 Gasoline (RVP 10) 2,430.78 6.92 r 2,437.69 Water 5,250.12 14.94 5,265.06 file:///C:/Program%20Fi1es%20(x86)/Tanks409d/summarydisplay.htm 10/13/2014 NGL Water Solutions DJ, LLC Facility: C5 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/Ib-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 Di, LLC Facility: CS Salt Water Disposal Facility Permit #: TBD AIRS ID: TBD Process Piping Fugitives Calculation Component Type Emission Factors' Source Count Percent VOC Hours of Total HC Total VOC Emissions Total VOC Operation Emissions Emissions (!b/hr/source) ha (lb/hr) (lb/hr) TPY 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 -Light 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 364 100.00% 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 1 TOTALS: 1.31 1.06 4.65 HAPs Component Wt% lb/hr ton/yr lb/yr BZ 0.53% 0.01 0.03 61 Not Reportable Tol 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 #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 for the AVO program NGL Water Solutions DJ, LLC CS 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 S 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 C30 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% % of Hydrocarbons Mass % Vol `)/0 MoI% Mass % Vol % Mol% 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-methylpentane 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 1 c,3-dimethylcyclopentane 0.261 0.26 0.316 0.41 % 0.41 % 0.50% 6.449 684 N7 1 t,3-dimethylcyclopentane 0.307 0.305 0.372 0.49% 0.48% 0.59% 6.551 686.76 N7 1t,2-dimethylcyclopentane 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 1 c,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-methylhd 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 lt,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 ethylbenzene 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-dimethylheptane 0.101 0. 103 0.094 0.16% 0.16% 0.15% 16.714 869.79 19 3,4-dimethyiheptane 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-trimethylcyclohexane 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-methyinonane 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 1 t-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 1014.14 111 127 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-butyl benzene 0.138 0.119 0.122 0.22% 0.19% 0.19% 25.395 1052.81 111 134 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 .14111 136 0.169 0.17 0.129 0.27% 0.27% 0.20% 25.769 1064.13 111 138 0.161 0.161 0.122 0.25% 0.25% 0.19% 25.885 1067.61 A10 1 ,4,dimethyl-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 1073.51 111 140 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 1085.29 111 143 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 A11 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 A11 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-tetra methyl benzene 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 A11 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 A11 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 ,2,3,4,5-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 A11 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 + O14+ 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 + C14+ 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, I C0 irr ENTRE PROFESSIONAL OFFICE PARK 1012 Centre Avenue /4 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: 8528-03 Matrix: Water HAZARDOUS AP POLLUTANTS CAS Concentration Concentration Number Compound Analyzed (mg/L) (0/0 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 110-54-3 n-Hexane 11909 1.1909 98-82-8 Isopropylbenzene 247 0.0247 QA/QC SURROGATE RECOVERIES Compound °/0 Recovery 0/0 Rec. Limits Dibromofluoromethane 89 68-120 1,2 Dichloroethane-d4 86 70-119 Toluene-d8 96 80-114 Page 2 of 20 TECH No^:, * LOGY LABORATORY, INC. CENTRE PROFESSIONAL OFFICE PARK / 1012 Centre Avenue Fort Collins, Colorado 80526 (970) 490-1414 CECIFECAT OF ? 1ALYS'S 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:\Chem32\1\DATA\TLI\DHA-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:\Chem32\1\DHARef\PONA-VI.DHA Comments: Normalized to 63.2300% SUMMARY REPORT Group Type Total(Mass%) Total(Vol%) Total(Mor/o) 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%) Multisubstituted Aromatics: 6.4361(Mass%) 5.4603(Vol%) Average Molecular Weight: 118.2459 Relative Density: 0.7395 Vapor Pressure: 1 .9843 Calculated Octane Number: 62.2351 IBP T10 T50 T90 FBP Boiling 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:\Chem32\1\DATA\TLI\DHA-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:\Chem32\1\DHARef\PONA-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 0.753 010 140. 135 0.766 C11 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 'so-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\TLl\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:1Chem32\11DHARef1PONA-VI.DHA Comments: Normalized to 63.2300% Totals by Group Type & Carbon Number (in Mass Percent) Paraffins l-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 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 0.05253 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 O10 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:\Chem32111DATA\TLI\DHA-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:\Chem32\1\DHARef1PONA-VI.DHA Comments: Normalized to 63.2300% Totals by Group Type & Carbon Number (in Mol 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 0.09532 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 010 1 .50466 3.10476 0.04047 0.24221 1 .56313 6.45524 011 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 014+: 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:\Chem3211\DATA\TLI\DHA-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:1Chem32111DHARef\PONA-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 °A Volume c/o 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 17 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 1c,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 1t,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 18 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 1c,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 18 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 1 c,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:\Chem3211\DATA\TLI\DHA-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:\Chem32111DHARef1PONA-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 N8 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 P8 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 lc,2t,4c-trimethylcyclohexane 0.037 0.036 0.035 17.738 882.980 N9 1c,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 N9 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 I11 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:\Chem3211\DATA\TLI\DHA-061709-8528-02.D\DHA-061709-8528-02.CDF Acquired: 06/17/09 11 :15:44 1 Sample: Condensate-001 Analyzed: 6/18/2009 11 :31 :41 AM Processed 233 Peaks Reference File: C:\Chem32\11DHARef\PONA-VI.DHA Comments: Normalized to 63.2300% NOTE: Components with a Weight To 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 1014.140 111 127 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 1024.540 111 130 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\TLI\DHA-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: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: 8 Minutes Index Group Component Mass % Volume % Mol % 24.877 1036.830 111 132 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 Al 0 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 Ill 134 0.038 0.039 0.029 25.485 1055.550 Nil N41 0.140 0. 129 0.107 25.592 1058.820 111 135 0.034 0.035 0.026 25.669 1061 .140 111 136 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,dimethyl-2-ethylbenzene 0.241 0.204 0.213 25.926 1068.850 Al0 A3 0.042 0.036 0.037 25.981 1070.500 111 139 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. 170 All 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 All 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 Al0 5-methylindan 0.149 0. 125 0. 134 27.948 1137.040 All 1 ,2-ethyl-n-propylbenzene 0.237 0.197 0.190 28.039 1140.460 All 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:\Chem32111DATA\TLl\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:\Chem32111DHAReflPONA-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 A10 naphthalene 0.040 0.029 0.037 28.893 1172.310 A12 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 A12 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 0.044 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 Al2 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 A11 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-tridecane 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:1Chem32111DATA\TLI\DHA-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:1Chem32111DHARef\PONA-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 % Mol % 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 + C14+ 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 + 014+ 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 + C14+ 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 + 014+ 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:\Chem32111DATA\TLI\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:1Chem3211\DHARef1PONA-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 % Mal % 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. S a( cn n CT S 23 8 o C o c"°� `�-; P a " `E 8 o t g S c.." ; 84 2233 23 8 2 a `�' `g ? E CD --t m 3 IT, afro ca 0 0 b u. r C) 0 -1 m -. W CD n_) O it) o y Cr! ...� r_ �y ti X69538 : propane CO 60 Cr cc NJ F • z en abmn 1.4 CO t' : n -hexane 1+ C11 4T Ur Rt (ft Ur ' % -- 7 .0692 : n -heptane -1 ,r a i 1 . • (i.f Page 16 of 20 p ppSignal �v pp pp O G U O O O O O O O O Q O O O t� O q O O O O O 0 O O ul 0 CJI O 0 O C U 4 n FL; 72 ce Q CGS - - . vl _i cb a CD a `�Y-�••n • • t : 011) to Fif I th CS i • I ,. 7 ` . . a — . . . C) C ...= '.. r • ' ' < < , . . CD c w Ct. N • ' N I O •-i ce or • .. , •, 2 w ex) r.a CJ's NJ Co 12 .2743 •. n -octane ^' b EL . . .- - 0 co Oo C17 hJ CO O N .c... C----L- I T•[------ 1 • I 1 .t . f •. . • y• _ . -1. • . • •- I. .. . • • r . • CJ N CP CJt • • `Ls . ' . ' • ) �n• L• r .. t r .. , .. ,. I-:.: C.11 V .„ I ---J Ul co._._=.._i t Ct CO O1 '`mot • �`�n19 .1617 : n -nonane Lc • • N O Page 17 of 20 Signci qo o N P.O P.O N N co CJ CJ (. 1+ S. L . . C.n Wit ", '•�.x1 [a}, Ol C.') C7 v •' D v G 0 a o 0 u 0 C a 0 8 8 Q O° S OF F' ≥v a S c8 8 o 0 `tom a 4 6 di c-n to 3 a . • C9 r.,1 C f I CJt C, :".i _. r y� p . , /•N 171 () 0 , , J a cs C)1 -•/ - 1Pi • ., . . .4,. k'•• , m r , c7...._,.. ,....= . . , .t Islit).- s..„, .. o D ca = f 6 Z .71 O1 • $ w �. 0 o 1O 80 M .. CJI N c"• CSC` CJ, C.-* CO KJ• oi —23 .7265 : n-decane T' . _ 1 i ' } i• r . • . i .• ,.; n, . , , l'1.1 sis t+' 171\i L [P . . . . - . . 1 C.-1 . . n. .. ." Y N 0 I Cr 1 - .1 ' . . • - `" 26 .9911 : n -undecane • n • w•0 U ',. _ .. ... 1 r hJ or- - • - . r 1 • n • . • . •. ( 1 • Cil Pc t • r.• u, . Lrl it • X29 .6585 : n -dodecane - • Page 18 of 20 Signal 44 NJ 1:. c' f» N 4. C7, 00 S O O O W I-8 -8823 0 fV L Nara. CO U, N) £-� rn C C) n> L' I ) O (.0 c7 v o 0 0 �' o 0 0 �' S c� o n o 0 o o o o u ca o n _+ x'29 .6585 : n -dodecane ° ' , F •• • • y k K h •��l •LJ ' LT,.. • 1 i l o o - 3 cJ, w • . . °' c ti )u :• ;,' • • . • ; 1. •• ;CO --i • 7 _ J n r.. 6 W . 1 1 �•> Cr p� y j- .r • >. .1 Q J - u'931 .9885 : n -tridecane 0, Vti cn q W 1: •. � 0 ; ..l co Ln Co•• I • b -71 .0983 : C 14+ V14#44- 4 .2861 : C14 + a' •bt366 : GCi1�+ u, n 4 .8444 : C 14 + L., .1253 : C14 + 2 39 : C14 + T5 .3569 ; C 14 + cri Cri .4795 : C 114 + n :1j76 : 14+ W �' .0499 : C 14 + L., .5586 : C 14 + .6687 : C14 + .8956 : C 14 + • t2 c `1114 =3 .5904 : C 14+ �3 344 : C 14 + 37 .8761 : C 14 + .65 Cr, =3 566 : C 14 + 13.7696 3 : C 14 + 8.97254 1 C A14 + n .1207 : C14+ .6707 : C 14 + Littasoes . C t4 + Page 19 of 20 Technology Laboratory Inc. Centre Professional Office Park 1012 Centre Avenue Fort Collins, CO 80526 970-490-1414 info(aftechlabusa.com 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 Gravity 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 3ZA'1VNV lNOQ 'a1oH - SISA1VNV 1:131.11, tI u 1� 5 Cr ) "Milet?Yr )4 o ' -5( - - 4 4 0 d O X -1711 Da ❑ ' C w Dir?, .-D -O › ..d Et cr ��1 24 R (n >,.. Alb 111 D CD 980d �� m Zdo O © eH3 `tea 'r, QN) S3SV0 03X1.4FA h. 000 / 008 a CO us) m VII'Cl/I NV /311a1IN / 31Va1jN 0 > a Q Ui 2 a D D _ _ ► al w a w o a HdAl/ SI-01/ b1-01/ l-pl Mali v O w II 1z Jaw Lined / •Iao / .avu6l , .p a LL w (03A1OSSQ /dill/'WW1) swim g vim _ 1 i j a 6' OJ SS1 / Hd �� 1 < z z HVd / 0LZB / SO aoAS ► c-:-N ?.i m-- U dl3l / 14101 09Z8 / �Z9 `___A ..9 OQR 0 ui w ui b99 I / V£« aseaao I' I!O 1 A 4 I Veit Hal "_ _"� O 0-e 9 to (OHO Heal 1>< t`71-f-- • —1____ zt Og on , . A t Sa3NIV1NOa 3O a38WIN an Cie (O) tt3HiO (NIA S1103flom -. 42 d (v) aid (s) lips : um 3lditdS a 1 0 ,.„ maci 00E 0 >46N 00 o S" si. in i P .� C fii Ir C....) a• S EUj ' oo 0 i.11 � i� 21 < . x � CD '� w � r� i .- ....,—_,........46 m m � � � O to aw � wa z z r� W O `t d -- w v' } �' ® NH � 2 wfi; i El r w O w 04 oa ,� � � J 1 4 U a U ¢ Lim _. a a , �. _ _ +�.� w4 m tt jai CD Q ,20.• aii.N., z C 1 .1 m 11J 13 CC eC CC �r o ec 1 a0.--`: ; k4 4......... 4, b 1 Y E m -ii Emo Lk_ Q - ® FA:\ ac, no..... 0 t � 1 u-O o o xo 08 EE zz a Y 2 V 8 V V _- U �/ < , , s 7,-.3 i, 2 C[ RS 0 JO nff. d d V) J .— a 1 co O4 Cu) ECINOLIGY LABORATORY, ENC. / CENTRE PROFESSIONAL OFFICE PARK 1012 Centre Avenue / � 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. AL;c7 TECHNOLOGY 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 CorrectedAPI Gravity: 47.0 @ 60*F RVP: 3.2 # @100 *F Date Sampled: 6/15/09 DateAnalyzed: 6/24/09 Sampled By: N/A Analyzed By: Putnam Page 2 of 2 NGL Water Solutions DJ, LLC C5 Salt Water Disposal Facility Slop Oil Tank and Sale Oil Tank Emission Composition from E&P Tanks Molecular % Weight Weight VOC Liquid Constituent Weight Mole (Ib/Ibmole ° Corrected (Ib/Ib-mol) 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% 'so-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% 6/6% 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. W I W I W 1 W 1 W I W t W x I I I 1 I I I V I I I I CA.$T0PAOE 14182 Cf.NEAT Tµt SIP CAL Tµ[ SalE 04 TWA I I Ile le1 I Li I O O -•• T` -y O ' M -W/ ( - SAIL CO MO SLOP t4 I IRµULA POP V I 00 0 0 I 1 1 I I o: I I 1 I — _. I I II IROLEKEDAYDAIIYALLt1WTEL DTSWD TANK OA SAN TIM STOMP TA140 Cifµ Win I I 00 0 0 II I fey l/t WI v1 it © CI f �' O 1 --� Of av no. I I • I I I II I I 1 I41 I I •14 I I Q © I 1 ALTER MAP ~� Clan*Pop MlEM,.I.7W P) I I I CONTAINMENT AREA I PUMP HOUSE I $, --- - ---- --- - - --- ----- --- - - -•--I =1=1= I=I E A 1 PLANT CAPACITY= 20.000 BPD-TWO INJECTION WELLS Sµ MOER DCDOSAA OPP Watp% I Wl WI VI OepOll OI Da ent)OtW)na poi ES I it N I lAtl(in ! Tl 4 )1 l/ 71 YI aTt)Y, S) MS • HI Wilted 3 40 O OIY.tTWt WOy4•JY4. et MOO.WAWA. NeninalMC O.tnfayK. S1C4&LCEXapfOll {•_••AIUWJMJInpv pl,I.1SAtpt1 N.•D4 SALMI.CY t. t ) Lft)! 04.A. 0 ) IX NOW°OA own LL AlI 1; K ) 1 a 1 IWIIy1RfYlatrti 1 S Is I 1 }}} toWan » • K V1/I TOwutl�•l )OJ 10.0 WA A9 anentldfaf it l0A At? Ito Aq £' to M^SOt MCMJO *PO 1JC0 • on wen MOM I)pl LW )000 Wa AM IKlat Wtaut no St» to:O 1':0 KO AO) E APP SUPPICCDSCLEO WV SSW SOP I •S.b WK CYST INDI W4 '04 )S[ WA • J yeI % DALtOSOLWL Wit.41., 'LWO E1r0I/X U$O TOILICMTYZIICl Is i Sat WA • I IP 1 0 I - .ens. o.l:••. CS R Cwt a+ C5 SALTWATER PM '"1° ` ' 2 DISPOSAL FACILITY PROCESS FLOW DIAGRAM (�' ' - _ a:w <!T A ..•t "f^.x, t:... Water SolubocsDJ v—� Hello