AGREEMENT GOVERNING THE ACQUISITION

AND OPERATION OF DELAWARE CITY REFINERY

This Agreement is entered into this 31st day of May, 2010, between the State of 

Delaware Department of Natural Resources and Environmental Control (“DNREC”) and 

Delaware City Refining Company, LLC (“DCRC”) to address and clarify certain environmental 

regulatory considerations relevant to DCRC’s acquisition and operation of the Delaware City 

Refinery in Delaware City, Delaware (the “Refinery”). 

WHEREAS, The Premcor Refining Group Inc., a wholly-owned subsidiary of Valero 

Energy Corporation (“Premcor”), currently owns and operates the Refinery;

WHEREAS, Premcor has currently discontinued operations of equipment at the Refinery, 

and such equipment is undergoing preservation and maintenance activity;

WHEREAS, DCRC has executed an agreement with Premcor pursuant to which DCRC 

would acquire from Premcor the assets comprising the Refinery, and the Delaware City Pipeline 

Company, a corporate entity affiliated with DCRC (“DCPC”), has executed an agreement with a 

Premcor-related entity pursuant to which DCPC would acquire the assets comprising Premcor’s 

pipeline operations associated with the Refinery, with both agreements subject to certain 

contingencies specified in such agreements (the “Premcor Agreements of Sale”), and DCRC and 

Premcor desire to complete these asset transfers upon closing of such transactions (the 

“Closing”);

WHEREAS, DNREC and DCRC recognize that DCRC’s future operation of the Refinery 

requires the transfer from Premcor to DCRC of existing permits, authorizations and other 

regulatory approvals under various environmental statutes and regulations, and the Parties desire 

to ensure the prompt and lawful transfer of all such Permits within timeframes necessary to allow 

DCRC to resume operations of the Refinery following the current maintenance turnaround;
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WHEREAS, DCRC has identified opportunities to operate the Refinery in a manner 

consistent with historic operations and future objectives, while achieving environmental benefits

through modifications to certain existing Permits and regulations applicable to the Refinery;

WHEREAS, the Parties wish to clarify these permitting, regulatory and permit transfer 

issues to the extent possible to support the expeditious resumption of operations of the Refinery 

by DCRC upon the event of Closing and following the maintenance turnaround. 

NOW THEREFORE, DNREC and DCRC execute this Agreement to pursue these 

environmental and economic objectives.

I. Facility-wide NOx Emission Limit

A. Basis for Facility-wide NOx Emission Limitations

1. In accordance with the Federal Clean Air Act, 42 U.S.C. § 7401 et seq. 

(the “CAA”) and the Delaware Environmental Control Statute, 7 Del. C., Ch. 60, the State of 

Delaware, through DNREC, has promulgated regulations: (a) governing the permitting of certain 

new sources of air emissions and certain modifications to existing sources of air emissions, 7 

Del. Code Regs §1102 (Regulation 1102), (b) establishing comprehensive air quality operating 

permit requirements, referred to as “Title V Permits,” for major stationary sources of air 

emissions, 7 Del. Code Regs §1130 (Regulation 1130), and (c) establishing special permitting 

requirements for the review of proposed new major stationary sources or major modifications at 

existing major stationary sources of emissions of oxides of nitrogen (“NOx”) or volatile organic 

compounds (“VOCs”), identified as nonattainment “New Source Review” requirements, 7 Del. 

Code Regs §1125 (Regulation 1125). 
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2. The United States Environmental Protection Agency (“EPA”) has 

approved Regulation 1102 (December 7, 2006) and Regulation 1125 (February 7, 2001) for 

inclusion in Delaware’s State Implementation Plan (“SIP”).

3. Regulation 1125 establishes New Source Review requirements within the 

air quality control regions in Delaware designated as nonattainment for the National Ambient Air 

Quality Standard (“NAAQS”) for ground-level ozone, in accordance with the CAA. 

4. Regulation 1125 also includes provisions governing implementation of the 

New Source Review program in those air quality control regions for which the relevant criteria 

pollutant is designated as in attainment with the NAAQS, and thereby provides for the 

prevention of significant deterioration (“PSD”) of such air quality controls consistent with 

standards established under the CAA. 

5. Consistent with federal New Source Review regulatory provisions 

promulgated by EPA under the CAA, DNREC has interpreted Regulation 1125 as affording 

DNREC the authority to establish facility-wide emission limitations for specific pollutants as the 

permitting mechanism for ensuring a facility’s compliance with New Source Review 

requirements. 

6. The Parties intend to establish facility-wide emission limitations for NOx 

emissions from the Refinery (the “NOx Cap”) as the basis for evaluating the applicability of 

New Source Review related to NOx emissions under Regulation 1125. 

7. The Refinery is currently subject to Title V air quality operating permits 

which impose emission limitations governing numerous parameters, including NOx, for specific 
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air emission sources at the Refinery. The NOx emission limits identified in the Title V permit 

sum, in the aggregate, to more than 5,000 tons per year.

8. The Parties have agreed that the initial NOx Cap for the Refinery shall be 

2525 tons per year, evaluated over each 12 consecutive month rolling period, commencing with 

the twelve month rolling period comprised by CY2011. The NOx Cap will be further reduced to 

2225 tons per year, evaluated over each 12 consecutive month rolling period, commencing with 

the 12 month rolling period beginning on December 31, 2013 and ending on December 31, 2014. 

The NOx Cap will be further reduced to 1650 tons per year, evaluated over each 12 consecutive 

month rolling period, commencing with the 12 month rolling period beginning on December 31, 

2014 and ending on December 31, 2015. 

9. The Parties have also agreed to establish a plantwide applicability limit 

(“PAL”) for the attainment pollutant, nitrogen dioxide (“NO2”), in accordance with applicable 

PSD requirements under the CAA and Regulation 1125 (the “NO2 PAL”). DCRC will provide 

information to DNREC sufficient to establish the NO2 PAL in accordance with applicable PSD 

requirements.

10. The Parties acknowledge and agree that the compliance of the Refinery 

with Regulation 1125 and New Source Review standards with respect to NOx emissions shall be 

based upon the facility’s compliance with the applicable NOx Cap and NO2 PAL, as more 

specifically addressed herein. 

B. Implementation of the NOx Cap 

11. On or before August 15, 2010, DCRC shall submit to DNREC an 

application to modify the existing Title V operating permits for the Refinery to establish a NOx 
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Cap of 2525 tons per year governing all permitted sources at the Refinery (“Title V Permit 

Application”). 

12. DCRC may propose through the Title V Permit Application to eliminate 

individual NOx emission limitations or operational requirements that relate to a NOx limit for 

specific sources at the Refinery consistent with the criteria established below. DNREC may 

determine to retain an individual NOx emission limitation or operational requirement for a 

specific source to the extent that:

a. the limitation or requirement is specifically required for an 

emission source at the Refinery by an applicable federal New 

Source Performance Standard, promulgated at 40 CFR Part 60 

(“NSPS”), or Maximum Achievable Control Technology 

requirement, promulgated at 40 CFR Part 61 or Part 63 

(“MACT”); 

b. the limitation or requirement was imposed upon the source as a 

requirement of New Source Review for NOx emissions, applicable 

to the source through a prior permitting determination;

c. the limitation or requirement was imposed upon the source to 

avoid applicability of New Source Review for NOx emissions, 

specified for the source through a prior permitting determination;
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d. the limitation or requirement was incorporated into the Delaware 

SIP as a regulation expressly promulgated to achieve NOx 

emission reductions required under Title I of the CAA; or

e. relaxation of the limitation or requirement would result in a

modeled exceedance by that source of an ambient air quality 

standard (“AAQS”) or an increment violation.

13. The Title V Permit Application shall also include the following 

information: 

a. Designation of the existing conditions of the Title V Permits for 

which DCRC requests revisions through the application for permit 

modification, as well as DCRC’s proposed revisions to such 

provisions. 

b. Proposed methods for evaluating NOx emissions from individual 

sources, in accordance with Section I.C., below. 

c. Request to establish an initial NOx Cap of 2525 tons per year 

commencing with the rolling twelve consecutive month period 

comprised by CY2011, applicable to all sources of NOx emissions 

identified in the Title V permit, and to further reduce such NOx 

Cap for the Refinery to 2225 tons per year, commencing with the 

twelve month rolling period ending December 2014, and to 1650 
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tons per year, commencing with the twelve month rolling period 

ending December 2015. 

d. A proposal to establish a NOx emission cap for all NOx emission 

sources at the Refinery, applicable to emissions from such sources 

during the period of May 1 through September 30 of each calendar 

year (the “Ozone Season Cap”). DCRC shall propose the quantity 

of NOx emissions reflected by the Ozone Season Cap based on 

consideration of the quantity of NOx emissions for the applicable 

NOx Cap, the variability of production rates at the Refinery, and 

the higher production rates anticipated during the May 1 through 

September 30 time period. 

14. DCRC shall submit to DNREC a non-binding plan for achieving NOx 

emission reductions consistent with the emission limits reflected by each NOx Cap for the 

Refinery, according to the following schedule:

a. On or before January 1, 2011, DCRC shall submit to DNREC a 

non-binding plan reflecting DCRC’s then-current intentions to 

limit aggregate NOx emissions from permitted sources at the 

Refinery to 2225 tons per year, commencing with the twelve 

month rolling period ending in December 2014; and 

b. On or before January 1, 2013, DCRC shall submit to DNREC a 

non-binding plan reflecting DCRC’s then-current intentions to 

limit aggregate NOx emissions from permitted sources at the 
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Refinery to 1650 tons per year, commencing with the twelve 

month rolling period ending in December 2015.

c. These plans shall identify DCRC’s then-current expectation of 

NOx emission reductions to be achieved at specific individual 

sources, along with a statement of the anticipated control measures 

to be utilized and timelines for achieving such emission reductions. 

The Parties expressly recognize that the non-binding plans 

submitted by DCRC under this provision are intended only to 

reflect DCRC’s evaluation of available methods for limiting NOx 

emissions from permitted sources at the Refinery to the level 

approved by the relevant NOx Cap, and that such plans are neither 

binding nor enforceable. Instead, DCRC may determine to achieve 

compliance within the NOx Caps specified by means that are 

inconsistent with or contrary to methods identified in plans 

submitted to DNREC by DCRC under this paragraph, by all legal 

means. 

15. DCRC may elect to implement any lawful means to limit NOx emissions 

from permitted sources at the Refinery to a sufficient extent to satisfy the NOx Caps and NO2

PAL established in accordance with this Agreement; provided however that DCRC shall not 

remove any NOx emission control device, nor eliminate practices that are designed to reduce 

NOx emissions, existing as of the Effective Date, except in the event that DCRC installs a 

replacement NOx emission control device or practices designed to reduce NOx emissions for the 

source (after undertaking any appropriate permit process for any modification of the source), or 
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the source no longer emits NOx at a rate for which emission controls can be justified . This 

provision shall not restrict DCRC from adjusting the manner in which it utilizes any existing 

NOx emission control device, including by reducing the degree or extent of NOx emission 

control achieved by such device while maintaining compliance with all other applicable 

requirements.

16. To the extent that DCRC determines to implement any activity relevant to 

its compliance with any NOx Cap, and such activity requires prior authorization (“Approval”) 

from DNREC or any other federal, state or local agency, authority, board or other governmental 

instrumentality (“Government Authority”), then DCRC will timely apply for and make all 

reasonable efforts to obtain in a timely manner all appropriate Approvals (or determinations that 

no such Approvals are necessary or will be waived) for the construction or implementation of the 

activity relevant to DCRC’s compliance with the NOx Cap. Following submittal of its 

application for the necessary Approval(s), DCRC shall cooperate with the appropriate 

Government Authority by promptly submitting any additional information reasonably required 

by such Government Authority to process the pending application. 

17. In the event that, notwithstanding DCRC’s compliance with paragraph 16, 

a relevant Government Authority does not issue to DCRC, in a final form, any Approval 

determined by DCRC or such Government Authority to be necessary for DCRC’s lawful 

construction and/or operation of the relevant activity, then DCRC’s obligation to comply with 

the relevant NOx Cap shall be extended to the extent of the delay in securing the relevant 

Approval. For purposes of this paragraph, DCRC shall not be relieved of the compliance dates 

otherwise established for NOx Caps addressed herein by objecting to an Approval except to the 

extent that DCRC files a timely challenge or appeal, as applicable (“Appeal”), to such Approval, 
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that DCRC files such Appeal in good faith, and the specific challenges raised by DCRC through 

the Appeal materially bear upon and jeopardize DCRC’s ability to comply with the NOx Cap set 

forth in this Agreement. Further, DCRC commits to pursue an expeditious resolution of such 

Appeal, to the extent that procedures for expedited resolution are available for the subject 

Appeal. 

18. Following its review of the Title V Permit Application, DNREC will 

provide to DCRC a proposed draft modified Title V permit consistent with the provisions of this 

Agreement. The Parties commit to work cooperatively to secure the expeditious issuance of the 

final revised Title V Permit (the “Modified Title V Permit”). 

19. In the event that DCRC proposes to construct a new source of NOx 

emissions or modify an existing source, as such terms are defined under Regulation 1102, then 

DCRC shall submit to DNREC an application to construct or modify an air emission source, to 

the extent otherwise required by Regulation 1102. 

C. Source-Specific NOx Emission Determinations 

20. In order to demonstrate compliance with the NOx Caps, DCRC shall 

determine, on a monthly basis, NOx emission rates for each NOx emission source at the 

Refinery with emissions above relevant thresholds identified in Regulation 1102, in accordance 

with the provisions of this subpart. 

21. To the extent that an applicable federal regulatory standard specifies that 

NOx emissions from specific sources at the Refinery must be measured by continuous emission 

monitoring systems (“CEMS”), DCRC shall utilize CEMS in accordance with the applicable 

federal regulatory standards to measure the quantity of NOx emissions from such sources for 
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purposes of demonstrating compliance with the NOx Cap. Notwithstanding the foregoing, to the 

extent that any applicable federal regulatory standard governing the operation of a NOx CEMS at 

the Refinery requires data substitution methods relevant to compliance demonstrations under 

such applicable federal regulatory standard, DCRC need not utilize such data substitution 

procedures to determine NOx emission rates from the relevant source at the Refinery during any 

period of CEMS outage or out-of-control periods, if DCRC can identify an alternative basis for 

estimating NOx emissions from such source during such period of CEMS outage or out-ofcontrol. 

22. To the extent that a NOx emission source at the Refinery is currently 

equipped with a CEMS to monitor NOx emissions, then DCRC shall continue to operate such 

CEMS in accordance with applicable standards to measure the quantity of NOx emissions from 

such source for purposes of demonstrating compliance with the NOx Cap. For purposes of 

demonstrating compliance with the NOx Caps, the Parties do not currently anticipate that any 

additional CEMS shall be required for any existing NOx emission source at the Refinery, absent 

a new requirement for NOx CEMS imposed through a change in regulation or a modification to 

an existing NOx source at the Refinery. 

23. For each emissions unit at the Refinery currently equipped with a CEMS 

for NOx and required to operate such CEMS pursuant to paragraph 21 or 22, within 150 days of 

re-starting such emission unit, DCRC shall take such action as may be necessary and appropriate 

to ensure the continued accuracy of the NOx emissions monitored and recorded by the relevant 

CEMS data acquisition and handling system (“DAHS”). Thereafter, DCRC shall satisfy the 

QA/QC requirements specified for CEMS in the Refinery’s Title V permit.
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24. To the extent that any applicable regulatory standard requires DCRC to 

conduct performance testing for NOx emissions for a specific source at the Refinery, DCRC 

shall determine the NOx emission rate for such source based upon the NOx emission factor 

derived from the most recent performance test conducted in accordance with the applicable 

regulatory standard; provided however that DCRC may, at its election, conduct performance 

testing in addition to that required by applicable standards to establish a lower NOx emission 

factor for such source to be used in demonstrating compliance with the NOx Caps, provided 

however that DCRC must secure advanced approval from DNREC of any proposed adjusted 

NOx emission factor. DNREC shall approve or disapprove any request made by DCRC for an 

adjusted emission factor within 90 days of receiving information from DCRC sufficient to allow 

DNREC to determine the acceptability of such adjusted emission factor. 

25. For any permitted NOx emission source at the Refinery that is not required 

to determine NOx emission rates by operations of a CEMS or by conducting performance testing 

pursuant to paragraphs 21, 22 or 24, DCRC shall determine NOx emissions for such source in 

accordance with the Modified Title V Permit, for purposes of demonstrating compliance with the 

NOx Caps. DCRC shall propose through its Title V Application one of the following 

compliance demonstration methods: 

a. Installation and operation of CEMS; 

b. Determination and use of NOx emission factor based upon the results 

of the most recent performance testing conducted in accordance with a 

protocol approved by DNREC, or performed in accordance with 
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applicable performance testing methods established and published by EPA 

and appropriate for measuring NOx emissions from the relevant source; 

c. Published NOx emission factors for such source or category of 

sources;

d. Any other method approvable by DNREC.

26. For purposes of demonstrating compliance with the NOx Caps, DCRC 

shall account for NOx emissions from permitted sources during all periods of startup, shutdown 

or malfunction of such equipment. To the extent that such emission rates are not measured by 

CEMS during such periods of startup, shutdown or malfunction, and to the further extent that 

performance testing for such source did not establish emission factors for such equipment 

reflective of operations during periods of startup, shutdown or malfunction, then DCRC shall 

estimate such emission rates from such source during any periods of startup, shutdown or 

malfunction in accordance with best engineering judgment, provided however that DCRC must 

report to DNREC the basis for DCRC’s emission projections in such instance, and DNREC may 

object to DCRC’s emission estimation methodology. In such event, the Parties shall work 

cooperatively to resolve any such dispute concerning the propriety of such emission calculation 

method. Nothing in this paragraph shall be construed to waive, limit or otherwise restrict 

DNREC’s ability to bring an enforcement action against DCRC for compliance with the NOx 

Cap should DCRC operate prior to resolving any dispute with DNREC regarding the propriety of 

any emission calculation method, but subsequent to DNREC’s notification to DCRC of 

DNREC’s objection to DCRC’s emission calculation method, where DCRC would not have 

complied with the applicable NOx Cap but for its reliance on such emission calculation method.
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D. Recordkeeping and Reporting

27. On or before July 1, 2011, DCRC shall submit to DNREC a report of the 

annual NOx emissions for NOx emission sources at the Refinery, for the twelve (12) month 

period ending with May 31, 2011. 

28. On or before January 31, 2012, and every six months thereafter, or in 

accordance with a similar schedule established in the modified Title V permit, DCRC shall 

submit to DNREC a report of the annual NOx emissions for NOx emission sources at the 

Refinery, determined in accordance with the methods identified in Section I.C., above for each 

rolling twelve (12) month period concluding during the prior semiannual period.

29. DCRC shall maintain, for a period of five (5) years from the date of the 

compliance demonstration for each NOx Cap, records necessary to demonstrate compliance with 

the NOx Caps established in accordance with this Agreement. To the extent that DCRC 

determines NOx emission rates by use of CEMS, then such records shall consist of the data 

generated by the DAHS associated with the CEMS. Where NOx emissions are determined in 

accordance with emission factors derived from performance testing, DCRC shall maintain copies 

of all performance tests, as well as the hours of operation and throughput rate for relevant 

sources, to the extent applicable to determining NOx emissions for such sources. To the extent 

that DCRC determines NOx emissions for a specific source based upon published emission 

factors, then DCRC shall maintain copies of the information constituting the source of such 

emission factors, as well as records of the operating hours and/or throughput rate for such 

equipment, to the extent applicable to the determination of NOx emission rates for such source. 

DCRC shall maintain records of all periods of startup, shutdown and malfunction of permitted 

NOx emission sources at the Refinery, in addition to such other information concerning such 
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startup, shutdown or malfunction event necessary to determine emissions from such source in 

accordance with Section I.C. of this Agreement.

E. Compliance Evaluations Under NOx Caps

30. The Parties intend that the Modified Title V Permit issued under this 

Agreement shall establish the compliance obligations applicable to the Refinery relative to NOx 

emissions from permitted emission units at the Refinery. However, no NOx Cap or NO2 PAL 

shall become applicable to the Refinery prior to issuance of the Modified Title V Permit. 

DCRC’s compliance with the NOx Caps established under this Agreement and the Modified 

Title V Permit shall ensure DCRC’s compliance with nonattainment-New Source Review, PSD 

requirements and Regulation 1125 relative to NOx emissions. For purposes of implementing 

the NOx Caps, the Parties agree that no change to Delaware regulations other than Regulation 

1142 will be required.

31. DCRC’s compliance with each NOx Cap shall be determined based upon 

the aggregate NOx emission rates reported by DCRC for relevant sources during each twelve 

month rolling period, determined in accordance with Section I.C. of this Agreement.

32. To the extent Premcor has generated and/or preserved at the Refinery net 

emission reductions for any regulated pollutant other than NOx, and such net emission 

reductions have either been established as creditable emission reductions, or otherwise meet the 

criteria to be established as creditable emission reductions, pursuant to Regulation 1125, then 

such net emission reductions are preserved and transferred to DCRC for use in accordance with 

Regulation 1125, including in the context of any permitting and/or new source review/PSD 
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applicability determination relative to the construction, modification or reconstruction of any 

emission unit at the Refinery. 

F. Relationship to Other Regulations

33. Prior to the creation of any NOx Cap for the Refinery, DNREC had 

promulgated Specific Emission Control Requirements for NOx emissions from identified sources 

at the Refinery, at Title 7, Regulation No. 1142 (“Regulation 1142”). Consistent with the 

objective of establishing a NOx Cap for the Refinery, the Parties agree that Regulation 1142 

should be revised to reflect that the owner or operator of a refinery source of NOx emissions 

listed in Regulation 1142 may elect to comply with an NOx Cap established by DNREC for such 

Refinery, in lieu of complying with certain specific NOx emission limitations otherwise 

established through Regulation 1142. 

34. DNREC therefore agrees to propose and promulgate in accordance with 

Delaware law revisions to Regulation No. 1142 consistent with the provisions of this Agreement. 

On or before September 1, 2010, DNREC will initiate any applicable procedural requirements to 

promulgate revisions to Regulation No. 1142 consistent with the provisions of this Agreement. 

35. DNREC will submit to EPA a request to modify the Delaware SIP to 

reflect the revised version of Regulation No. 1142 identified in paragraph 34, and take all actions 

necessary to support and secure the requested SIP revision. DCRC agrees that it will not file any 

legal objection or challenge to DNREC’s proposed revised version of Regulation No. 1142 or 

corresponding proposed SIP revision, if such proposed revisions are consistent with the 

provisions of this Agreement.
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36. DNREC acknowledges that it does not currently contemplate the 

promulgation of any regulation requiring, or other legal standard having the effect of requiring, 

NOx emission reductions from the Refinery, except as otherwise provided by this Agreement. 

II. Additional Air Quality Considerations

A. Coke Storage

37. DCRC’s future operation of the Refinery in substantially the same manner 

as operated by Premcor would result in the production of petroleum coke from the Fluidized 

Coking Unit (“FCU”). DCRC will undertake to construct and/or modify a coke management 

control system with the objectives of minimizing the generation of fugitive coke dust and 

preventing migration of any airborne fugitive coke dust beyond the property boundary of the 

Refinery in a quantity and form that would otherwise cause air pollution, as defined at 7 Del. 

Code Regs §1101, or cause or contribute to monitored exceedances of the State’s AAQS for total 

suspended particulates (“TSP”).

38. As and to the extent required by applicable regulatory standards, DCRC 

will submit to DNREC an application for air quality construction and/or operating permit 

authorizing the construction and modification of equipment to effectuate the purposes of 

paragraph 37. DNREC will thereafter undertake all actions necessary to issue the final air

quality permit authorizing DCRC to proceed with the actions contemplated for implementation 

of enhanced coke management at the Refinery (the “Coke Storage Permit”) in accordance with 

Delaware law. 

39. DCRC will not operate the FCU in a production mode in a manner that 

produces material quantities of petroleum coke prior to receiving the Coke Storage Permit from 
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DNREC and constructing and commencing operation of the equipment authorized by such 

permit to support the effective management of petroleum coke in accordance with paragraph 37.

40. Premcor has operated existing ambient air quality monitoring stations at 

and around the Refinery in order to measure ambient concentrations of TSP. During the current 

maintenance turnaround of the Refinery, DCRC shall not be required to continue to operate or 

maintain such ambient air quality monitors. In addition, DCRC may propose, for DNREC 

review and approval, a new location for any existing ambient air quality monitor. Following 

resumption of operation of the FCU and associated production of petroleum coke, DCRC will 

resume operation of the ambient TSP monitors. DCRC will continue to operate the existing 

ambient TSP monitors until the date on which DCRC has collected data that demonstrates 

attainment for one year at the ambient TSP monitors with the Delaware AAQS for TSP. 

B. Propane Storage

41. DCRC will not introduce any propane gas produced at the Refinery into 

the existing underground Frozen Earth Storage (“FES”) unit at the Refinery, which is currently 

undergoing closure activities undertaken by Premcor. The completion of closure of the FES unit 

will remain the responsibility of Premcor. DCRC will ensure adequate capacity for propane 

storage, exclusive of the FES unit, for the quantity of propane gas that DCRC intends to produce 

and store at the Refinery. 

C. Completion of Repair of LDAR Components

42. Certain pumps, valves and flanges in gaseous or light liquid service at the 

Refinery are subject to federal and/or state regulatory standards governing leak detection and 

repair (“LDAR”). In the course of implementing its LDAR program for regulated components at 
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the Refinery, Premcor identified certain components which exhibited leak rates above action 

levels, but for which Premcor determined it necessary and appropriate to place such components 

on the “delay of repair” list. Prior to resuming full-scale production operations of the Refinery, 

DCRC shall perform repairs of all regulated LDAR components at the Refinery which had 

remained on the delay of repair list developed by Premcor, to the extent that Premcor identified 

to DCRC that such component remained on the delay of repair list as of Closing, and to the 

further extent that DCRC would resume the use of such component in a manner that would 

subject it to federal or state regulatory standards under applicable LDAR regulations. 

III. Water Quality and Discharge Matters

A. Discharge Permit

43. DNREC previously issued to the Refinery National Pollutant Discharge 

Elimination System (“NPDES”) permits designated by permit numbers DE005061 and 

DE0000256, authorizing the operation of water intake structures and the discharge of process 

and non-process wastewater from the Refinery (the “Discharge Permits”). 

44. More than six months prior to the expiration date identified for the 

NPDES permit applicable to primary Refinery operations, the then-current owner of the 

Refinery, Motiva Enterprises LLC (“Motiva”), had submitted to DNREC an application for 

renewal of the discharge permit. More than six months prior to the expiration date identified for 

the NPDES permit applicable to operations of the power plant at the Refinery, Premcor had 

submitted to DNREC an application for renewal of the discharge permit. The Refinery’s 

applications for reissuance of the Discharge Permits remain pending before DNREC. 
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45. In accordance with applicable federal and state law, the Discharge Permits 

are administratively extended and continue to authorize the operation of intake structures and 

discharges of both process and non-process wastewater from the Refinery to navigable waters in 

accordance with the terms of the Discharge Permits. Through the permit transfer provisions 

otherwise addressed in this Agreement, the Parties intend that these administratively-extended 

Discharge Permits will be transferred to DCRC, and continue to authorize the operation of intake 

structures at, and the discharge of process and non-process wastewater from, the Refinery in 

accordance with the terms of the Discharge Permits, until such time as DNREC reissues the 

Discharge Permits for the Refinery in accordance with the process described in the following 

paragraphs. 

46. Five months before the date that DCRC intends to resume normal 

operations of the Refinery, DCRC will endeavor to submit, and in any event on or before 

December 31, 2010, DCRC will submit, to DNREC an update to the pending applications for the 

renewal of the Discharge Permits, to the extent required by applicable law and necessitated by 

DCRC’s intended changes to operation of the Refinery, relative to that reflected in the pending 

application for renewal of the Discharge Permits (the “Updated Application”). 

47. Prior to issuing any new Discharge Permits, DNREC shall provide to 

DCRC a proposed draft permit (the “Draft New Discharge Permit”). The Draft New Discharge 

Permit will be based upon information in the existing applications for renewal of the Discharge 

permits, information provided by DCRC through the Updated Application, relevant information 

provided to DNREC and applicable federal and state guidance and law. 
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48. The Draft New Discharge Permit will include a best technology available 

determination (“BTA determination”) reflecting DNREC’s best professional judgment to address 

section 316b of the federal Clean Water Act related to the design and operation of the cooling 

water intake structure. In making the BTA determination, DNREC will consider federal and 

state law, including applicable federal case law, regulations and guidance, and specifically 

address cost considerations when making the determination. The Draft New Discharge Permit 

will include a compliance schedule for implementation of the BTA determination which will 

require DCRC to take such actions as necessary to construct the BTA during the five year period 

following the first five years of the New Discharge Permit term, as defined below. The Draft 

New Discharge Permit compliance schedule will also authorize DCRC to undertake a 

study/evaluation, during the five year term of the New Discharge Permit, to analyze site-specific, 

environmental and technology-based factors relevant to the benefits of alternatives to the BTA 

determination (“DCRC’s BTA Evaluation”). To the extent that DCRC determines that an 

alternative BTA standard is supported by DCRC’s BTA Evaluation, conducted during the first 

five years of the New Discharge Permit, then DCRC may submit to DNREC, as an attachment to 

its application for renewal of the New Discharge Permit, its proposal for, and the basis of, an 

alternative BTA determination. DCRC shall not be required to construct the BTA as determined 

in the New Discharge Permit, until DNREC notifies DCRC of the conclusions of DNREC’s 

reevaluation of the BTA determination, given consideration of DCRC’s alternative BTA 

standard. 

49. Within 30 calendar days of receiving the Draft New Discharge Permit 

from DNREC, DCRC will provide to DNREC any comments, corrections, questions or proposed 

revisions concerning the Draft New Discharge Permit. The Parties will address such comments, 
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questions and proposed revisions consistent with the terms of this Agreement. Following 

completion of such process, DNREC will take all necessary procedural steps to formally issue 

the Draft New Discharge Permit as a final renewal of the Discharge Permits. The final new 

discharge permit (the “New Discharge Permit”) may vary from the Draft New Discharge Permit 

based on consideration of relevant and applicable comments garnered from the public notice 

process such as comments from EPA, the public or DCRC, as required by law.

50. DCRC shall comply with requirements of the Delaware River Basin 

Commission Docket No. D-93-4-6 for taking any such actions necessary to reduce, by December 

31, 2013, the quantity of surface water drawn from the Delaware River at the primary cooling 

water intake structure from 452 million gallons per day (“mgd”) to 303 mgd, measured as a 12 

month rolling average. 

51. To the extent otherwise enforceable under applicable state and federal 

laws and regulations, DCRC shall comply with all obligations of the Delaware River Basin 

Commission (“DRBC”) and the Delaware River Estuary PCB Total Maximum Daily Loads 

(“TMDLs”). These requirements include, but are not limited to, implementing and annually 

updating the PCB Pollutant Minimization Plan and PCB Congener Monitoring with the objective 

of identifying any sources of PCB discharge, in accordance with the “Implementation Plan for 

Polychlorinated Biphenyls (“PCBs”) For Zones 2-6 of the Delaware Estuary.”

B. Dredging Activity

52. DNREC previously issued to Premcor a permit (the “Dredging Permit”) 

authorizing the maintenance dredging of sediment both in the berthing area and the navigation 

channel located within the Delaware River adjacent to the Refinery (the “Berthing Area and 
23

Navigation Channel”), and the maintenance dredging of a tidal channel which conveys water to 

the primary cooling water intake for the Refinery (the “Cooling Water Intake Channel”). 

53. Prior to the expiration of the Dredging Permit, Premcor submitted to 

DNREC an application to renew the Dredging Permit. Such application remains pending before 

DNREC.

54. Within five days of the Effective Date, DCRC shall submit to DNREC 

information confirming that DCRC requests issuance of the dredging permit in a form materially 

consistent with the terms of the pending application submitted by Premcor, including a request 

for a 10 year permit. In accordance with this Agreement, the Refinery’s pending application to 

conduct maintenance dredging in the Berthing Area and Navigation Channel and associated with 

the Cooling Water Intake Channel shall then be transferred to DCRC. 

55. On or before June 15, 2010, DNREC will conclude its administrative 

process and take action on the permit application referenced in the foregoing paragraphs for the 

dredging activity in the Berthing Area and Navigation Channel and the area associated with the 

Cooling Water Intake Channel (the “DCRC Dredging Permit”). 

56. DNREC anticipates that the DCRC Dredging Permit will authorize 

requested dredging activity for a period of ten years, and require the payment by DCRC of fees 

or compensation, as follows: 

a. To the extent that dredging during any event authorized under this 

DCRC Dredging Permit exceeds the depths previously authorized under 

Subaqueous Lands Permit SP-320/04 and Water Quality Certification 
24

WQ-320/04, then DCRC shall pay to the State of Delaware a fee of 

$1.50/cubic yard for the amount of material dredged in excess of the 

amount that would have been dredged at the depths previously 

authorized under Subaqueous Lands Permit SP-320/04 and Water 

Quality Certification WQ-320/04; and 

b. DCRC shall pay a one-time amount of $247,500 (for the creation and 

restoration of wetland habitat), by September 1, 2012, as compensation 

based on DNREC’s determination of adverse environmental impacts to 

benthic organisms and habitat that DNREC believes could result from 

the proposed dredging activity in the Berthing Area and Navigation 

Channel during the ten year term of the DCRC Dredging Permit; and 

c. During each year in which dredging is conducted in the Cooling Water 

Intake Channel, DCRC shall be obligated to pay $135,000 per year, as 

compensation, based on DNREC’s determination of secondary adverse 

impacts to aquatic resources that DNREC believes could result from the 

proposed dredging activity in the Cooling Water Intake Channel the 

(“Aquatic Resources Mitigation Compensation”). DCRC may remit the 

Aquatic Resources Mitigation Compensation to DNREC following the 

end of the first five years of the DCRC Dredging Permit (i.e., years six 

through ten of the term of the DCRC Dredging Permit) in increments of 

$270,000 annually. Without limitation to its option to remit payments 

during years six through ten rather than years one through ten, DCRC 

may elect to remit its payments to a dedicated account controlled by 
25

DCRC, rather than to DNREC (the “Mitigation Compensation 

Account”). All funds placed by DCRC in the Mitigation Compensation 

Account must be expended toward construction of BTA, determined for 

the cooling water intake structure in accordance with Section II.A, 

above, or directed to DNREC by the expiration date of the DCRC 

Dredging Permit or the transfer of the controlling interest in the Refinery 

from DCRC to any independent third party, whichever occurs first; and

d. By execution of this Agreement, DCRC does not thereby concur that the 

proposed dredging activity would cause adverse environmental impacts, 

that any adverse environmental impacts resulting from such dredging 

warrant or require compensation under applicable law, that any dredging 

activity would cause indirect adverse environmental impact or that any 

such indirect adverse environmental impact implicates the need for or 

requirement of mitigation under applicable law.

57. On or before June 15, 2010, DNREC will conclude its administrative 

process and take action on the Federal Consistency Certification concerning the dredging activity 

authorized by the DCRC Dredging Permit. 

IV. Regulatory Status of Refinery During Maintenance Activities

58. Premcor had stated its intention to permanently cease operations of 

primary refinery operations at the Refinery. Prior to reaching agreement with DCRC for the sale 

of the assets comprising the Refinery, Premcor initiated the temporary cessation of operations at 

the Refinery, pending implementation of a program to permanently cease operations. In the 
26

context of its efforts to ensure the safety and environmentally protective re-start of Refinery 

operations, DCRC intends to perpetuate the maintenance turnaround of equipment at the 

Refinery to ensure that the re-start of such equipment can be performed in a safe and 

environmentally protective manner. 

59. DNREC interprets the existing Title V Permits for the Facility, and will 

interpret the Modified Title V Permit for the Refinery, not to require compliance with 

monitoring, reporting, recordkeeping or operational standards identified for emission sources at 

the Refinery during the periods that such sources are not operating, on the basis that such 

requirements are intended to apply during operation of the relevant emission units.

60. DNREC characterizes the on-going activity at the Refinery initiated by 

Premcor and to be continued by DCRC as not inconsistent with historic practices at the Refinery. 

61. In this context, raw materials, product, feedstock and other materials 

associated with production operations at the Refinery (collectively, “Materials”) shall not be 

deemed to constitute waste material, pending a determination by DCRC (to be made within 3 

months of Closing) that any such Materials do not constitute usable product or raw materials. 

Upon any such determination, regulatory standards applicable to the proper characterization of 

the waste material would be initially triggered, including the commencement of waste 

accumulation periods under applicable standards. 

62. Similarly, material transfers among tanks and tank systems at the Refinery 

will be deemed to continue during the maintenance turnaround operations for purposes of federal 

and state storage tank regulatory standards. Accordingly, except as addressed in separate 

notifications or registrations submitted to DNREC by Premcor since Premcor’s initiation of the 
27

current maintenance turnaround activity at the Refinery, the regulated storage tanks and tank 

systems at the Refinery shall not be deemed to have experienced a change in use, nor to have 

been temporarily or permanently closed, during the ongoing maintenance activity at the 

Refinery, for a period not to exceed June 1, 2011 (unless extended by DNREC upon request by 

DCRC).

63. Based upon the State’s characterization of the status of activities at the 

Refinery, Premcor’s temporary cessation of operations shall not constitute an abandonment of 

the pre-existing industrial operation, and the equipment and operations at the Refinery will be 

deemed as a pre-existing use for purposes of the Delaware Coastal Zone Act, 7 Del. C., Ch. 70. 

Therefore, assuming that DCRC restarts refining operations prior to March 1, 2012, the re-start 

of such operations by DCRC following the maintenance turnaround shall not constitute a new 

activity in the Delaware Coastal Zone requiring the need for any Coastal Zone Act approvals or 

status decisions. 

V. Resolution of Outstanding Compliance Orders and Agreements Relevant to the 

Refinery

64. The Parties recognize that DNREC has initiated certain enforcement 

actions alleging non-compliance at the Refinery under various state and federal environmental 

statutes and/or regulations, and otherwise identified conditions of potential non-compliance 

based upon activities of owners and/or operators of the Refinery other than DCRC. DNREC 

acknowledges that any such enforcement activity, whether or not formally initiated, does not 

relate to any operations or activities by or on behalf of DCRC. This provision does not relieve 

DCRC of liability for any alleged noncompliance that may result from DCRC’s operations at the 

refinery after Closing.
28

65. DNREC hereby confirms that any prior enforcement action initiated by it 

against any owner or operator of the Refinery, other than DCRC, including in the form of any 

citations, notices, orders, complaints, investigations, enforcement agreements, or any other form 

of allegations of noncompliance, whether administrative, civil, criminal, judicial or otherwise 

(collectively, “Enforcement Actions”), concerning the Refinery does not apply to DCRC’s 

operations at the Refinery, is not transferred in any manner to DCRC, and does not impose any 

continuing obligations applicable to DCRC, except as expressly identified below:

a. Conciliation Order in the matter of the Premcor Refining Group Inc. –

Frozen Earth Storage, Secretary’s Order No. 2008-A-0051 (September 25, 

2008);

b. Consent Order in Nicholas A. Di Pasquale v. Motiva Enterprises, LLC; 

Civil Action No. 18750 NC in the Court of Chancery of the State of 

Delaware in and for New Castle County (3/26/01) (the “18750 Order”).

With respect to the 18750 Order, the Parties acknowledge that the substantive obligations under 

such Consent Order have been satisfied, and DNREC will file a motion requesting the Court to 

terminate the 18750 Order within approximately 30 days of the Effective Date.

66. Consistent with the foregoing, DNREC acknowledges that, to the extent 

allowable by law, any alleged non-compliance at the Refinery prior to Closing would not bear 

upon the evaluation of the status of DCRC relative to the “chronic violator” designation 

identified in 7 Del. C., Ch. 79. 
29

67. The Parties acknowledge that State of Delaware has executed consent 

decrees by and among the State, the United States and Motiva, to which Premcor has become a 

party, and that such consent decrees have been entered by the Federal District Courts for the 

Southern District of Texas

1

and the District of Delaware2(collectively, the “Federal Consent 

Decrees”). The Parties further acknowledge that DNREC cannot unilaterally terminate the 

Federal Consent Decrees and, pursuant to the express terms of the Federal Consent Decrees, 

DCRC may become a party through addenda to the Federal Consent Decrees, and thereby be 

bound by any residual obligations imposed thereby.

68. The Parties believe that any obligations otherwise applicable to the 

Refinery under the Federal Consent Decrees have been substantively satisfied. Therefore, 

shortly following the Closing, DCRC intends to work with Premcor and, as appropriate, Motiva, 

to petition the Court for termination of the Federal Consent Decrees. DNREC will use its best 

efforts to support DCRC’s efforts in this context. 

VI. Transfers of Applicable Permits and Authorizations

69. Operation of the Refinery is governed by numerous permits, licenses and 

other authorizations relevant to specific equipment, media and regulatory programs.

70. The Parties intend to accomplish the prompt transfer from Premcor to 

DCRC of all existing permits, authorizations, approval, licenses, and other sources or grants of 

authority relevant to the operation or status of the Refinery (collectively, the “Authorizations”). 

In order to accomplish this prompt transfer of all relevant Authorizations, the Parties have 

 

1 United States v. Motiva Enterprises, LLC, Civil Action No. H-01-0978, S.D.Tx. (Consent Decree originally 

entered August 20, 2001), as amended.
30

compiled a table of Authorizations subject to and requiring transfer, which is included as 

Attachment “A” to this Agreement. The table included with Attachment A also identifies the 

specific procedure that shall be utilized to accomplish the transfer of the Authorizations.3 

Although the Parties have attempted to ensure the accuracy and completeness of the relevant 

table of Authorizations identified in Attachment A, due to the extent of such Authorizations, the 

Parties acknowledge that such list may not be fully complete and accurate. To the extent 

necessary for completeness and accuracy, DNREC will amend the table of Authorizations 

included within Attachment A within 30 days of Closing.

71. Based on its knowledge of the operations at the Refinery conducted by 

Premcor, DNREC has not identified any additional permit, authorization, approval, license, 

status decision or other sources or grants of authority, other than the Authorizations, required by 

DCRC to own or operate the Refinery in a manner substantially similar to the operations 

conducted by Premcor. To the extent that either Party identifies any additional requisite license, 

authorization, permit, approval, status decision, or other source or grant of authority, 

(collectively, “Other Necessary Approval”), then the Parties shall work cooperatively to secure 

issuance or transfer of such Other Necessary Approval as promptly as possible.

72. For purposes of satisfying any requirements as to the Environmental 

Permit Application Background Statement under 7 Del. C., Ch. 79 (“Chapter 79”) relevant or 

applicable to the transfer to DCRC or DCPC of Authorizations or Other Necessary Approvals, 

 

2

 United States v. Motiva Enterprises, LLC, Civil Action No. 02-1292-SLR, and Department of Natural Resources 

and Environmental Control v. Motiva Enterprises, LLC, Civil Action No. 02-1293-SLR, D.Del. (Consent Decree 

entered January 12, 2006.)

3 The table included within Attachment A identifies certain subaqueous land leases. As of the Effective Date, 

Premcor continues to pursue certain modifications and clarifications of these subaqueous land leases. Following 

Premcor’s appropriate modification, clarification or reinstatement of such subaqueous land leases, Premcor will 
31

DNREC has determined that the appropriate permit applicant shall initially be identified as the 

Delaware City Refining Company, LLC, or Delaware City Pipeline Company, as applicable, and 

all information to be supplied to DNREC under Chapter 79 shall be limited to DCRC or DCPC, 

as applicable, its officers, directors and subsidiaries, and not extend to any individual partners, 

shareholders or other related corporate entities. 

73. To the extent that the transfer from Premcor to DCRC of any 

Authorization requires notification to the State, or DNREC, such notice shall be deemed to have 

been completed as of the date that DCRC provided notice to DNREC of the Premcor Agreement 

of Sale.

74. To the extent that any appeal, hearing request or challenge filed by 

Premcor of any Authorization remains pending as of the Effective Date, the Parties agree to the 

transfer to DCRC from Premcor of such appeal, and the preservation of any challenges raised by 

Premcor through such Appeals. This provision is not intended nor shall have the effect of 

expanding the scope of any such appeal. 

VII. General Provisions

75. This Agreement shall be governed by, and interpreted under, the laws of 

the State of Delaware.

76. The Parties agree to cooperate and make all reasonable efforts to secure 

issuance in a timely manner of all appropriate Authorizations or Other Necessary Approvals 

required by DCRC to implement the objectives of this Agreement. Consistent with this 

 

work with the State and DCRC to accomplish the prompt transfer from Premcor to DCRC of such subaqueous land 
32

commitment, DCRC shall promptly respond to any written notice by DNREC requesting 

additional information or identifying deficiencies in any permit application submitted under this 

Agreement. Prior to issuing any final permit, DNREC shall provide DCRC with a draft permit 

reflecting the terms and conditions that DNREC proposes to include within the permit. DCRC 

and DNREC shall work cooperatively in an attempt to promptly resolve any disagreements 

concerning specific terms and conditions for inclusion in any permit.

77. Nothing in this Agreement shall limit or affect the rights of DCRC to 

contest, appeal or otherwise challenge any permit, and/or any other Authorization or Secretary’s 

Order issued by the Secretary, related to any permit identified by this Agreement. In the event 

that DCRC contests, appeals or otherwise challenges any permit and/or any other Order or 

Authorization issued by the Secretary related to any permit contemplated by this Agreement, 

then the Parties agree to attempt to cooperatively resolve any differences concerning the permit 

and/or request expedited review of such appeal or challenge before the Delaware Environmental 

Appeals Board.

78. This Agreement identifies the methods and processes by which DCRC 

shall ensure the compliance of Refinery Operations with certain applicable environmental, 

regulatory and statutory standards by satisfying standards or operating practices identified in this 

Agreement and, where appropriate, Authorizations granted to DCRC. Nothing in this 

Agreement shall relieve DCRC of its obligation to comply with all applicable federal, state and 

local laws and regulations. 

 

leases.
33

79. No provision of this Agreement shall have the effect of limiting the 

applicability of any regulations promulgated after the Effective Date, to the extent otherwise 

applicable to operations at the Refinery. 

80. Except as otherwise addressed in this Agreement, neither DNREC nor 

DCRC waives or otherwise limits, in any way, its rights, claims, positions or available defenses 

concerning applicability or interpretation of any specific regulatory or statutory provision 

potentially relevant to the compliance of DCRC’s operations at the Refinery.

81. By execution of this Agreement, DCRC does not waive or limit in any 

way its rights to contest any action by the State, including DNREC, including without limitation 

relative to DCRC’s rights to defend against, and available claims, positions and defenses in 

responding to, any compliance action initiated by the State, including DNREC. 

82. Upon issuance to DCRC of any Authorization or Other Necessary 

Approval, including without limitation the Modified Title V Permit, which incorporates or 

applies any obligation of the Parties under this Agreement, the obligation will no longer be 

separately enforceable under this Agreement.

83. Third Parties. This Agreement does not limit or affect the rights of 

DCRC or DNREC against any person or entity not party to this Agreement, nor does it create or 

expand any rights of any person or entity not party to this Agreement concerning or against 

DCRC or DNREC. In addition, this Agreement shall not be considered to create rights in, or 

grant any cause of action to, any third party not party to this Agreement.
34

84. Notice. Unless otherwise provided herein, notifications to or 

communications with DNREC or DCRC shall be sent either by overnight receipt mail service or 

by certified or registered mail, return receipt requested, or hand delivered. Except as otherwise 

provided herein, written notification or communication shall be addressed as follows:

As to DCRC:

James Fedena

Delaware City Refining Company, LLC

Delaware City Refinery

2000 Wrangle Hill Road

Delaware City, DE 19706

and

Jeffrey Dill, Esquire

General Counsel

PBF Investments LLC

One Sound Shore Drive, Suite 303

Greenwich, CT 06830

As to DNREC:

David Small, Deputy Secretary

DNREC

89 Kings Highway

Dover, DE 19901

Kathy Bunting-Howarth

Director of Water Resources

DNREC

89 Kings Highway

Dover, DE 19901

and 

Valerie Satterfield

Deputy Attorney General

Department of Justice 3rd Floor

102 W. Water Street

Dover, DE 19001
35

85. Either party may change either the notice recipient or the address for 

providing notices to it by serving the other party with a written notice setting forth such new 

notice recipient or address.

86. Binding Agreement. This Agreement shall be binding upon the Parties. 

DCRC shall not assign or otherwise transfer this Agreement without the prior written consent of 

the Secretary of DNREC. The undersigned representative of each Party to this Agreement 

represents that he or she is authorized by the Party whom he or she represents to enter into the 

terms of this Agreement and bind that Party to them.

87. Effective Date. This Agreement shall be effective upon the later date of 

execution by the authorized representatives of both Parties (the “Effective Date”). 

88. Closing as Prerequisite to Obligations Under the Agreement. This 

Agreement, and the commitments, obligations and understandings reflected herein, are 

dependent upon the successful completion of Closing between DCRC and Premcor regarding the 

transfer of assets comprising the Refinery. No obligation undertaken by DCRC or DNREC 

hereunder shall be binding in the event that the closing does not occur.

89. Modification. This Agreement may be modified only by the written 

consent of DNREC and DCRC.

90. Severability of Terms. If any part of this Agreement is for any reason 

found to be unenforceable, all other portions shall nevertheless remain enforceable.

91. This Agreement constitutes the entire agreement between the Parties.
36

FOR THE STATE OF DELAWARE 

DEPARTMENT OF NATURAL RESOURCES AND ENVIRONMENTAL CONTROL

By:_____________________________ Date: May 31, 2010

 

Collin O’Mara, Secretary

 Department of Natural Resources 

 and Environmental Control
37

FOR DELAWARE CITY REFINING COMPANY, L.L.C.

By: _____________________________ Date:________________

 Thomas J. Nimbly

 Executive Vice President and

 Chief Operating Officer