Document:

exv10w22

Exhibit 10.22

FTS Contract No. 71658

SERVICE AGREEMENT

(APPLICABLE TO RATE SCHEDULE FTS)

This Agreement (“Agreement”) is made and entered into this 1st day of September, 2008,
by and between Enbridge Pipelines (Midla) L.L.C., a Delaware Corporation (herein called
“Pipeline”), and Enbridge Marketing (US), LP herein called “Customer” whether one or more persons).

In consideration of the premises and of the mutual covenants herein contained, the parties do agree
as follows:

ARTICLE I

SCOPE OF AGREEMENT

	1.1	 	Subject to the terms, conditions and limitations hereof and of Pipeline’s Rate Schedule FTS,
Pipeline agrees to receive from or for Customer for transportation on a firm basis quantities
of natural gas up to the Maximum Daily Quantity (MDQ) tendered by Customer on any day at the
Point(s) of Receipt; provided, however, Customer shall not tender at any Point of Receipt on
any day a quantity of natural gas in excess of the applicable MDQ set forth on Exhibit A for
each such Point of Receipt or Customer’s nomination, if less than the MDQ, or in any year, a
cumulative quantity of natural gas in excess of the Maximum Annual Quantity (MAQ) inclusive of
the applicable Fuel Reimbursement Quantities. For purposes of this Agreement, the MDQ and MAQ
shall be as follows:

	 	 	 	 	 	 	 
	Maximum Daily Quantity	 	 	 	 	 	 
	January
	 	 	20,000	 	 	MMBtu
	February
	 	 	20,000	 	 	MMBtu
	March
	 	 	20,000	 	 	MMBtu
	April
	 	 	12,000	 	 	MMBtu
	May
	 	 	7,700	 	 	MMBtu
	June
	 	 	7,700	 	 	MMBtu
	July
	 	 	7,700	 	 	MMBtu
	August
	 	 	7,700	 	 	MMBtu
	September
	 	 	7,700	 	 	MMBtu
	October
	 	 	12,000	 	 	MMBtu
	November
	 	 	20,000	 	 	MMBtu
	December
	 	 	20,000	 	 	MMBtu

	1.2	 	Subject to the terms, conditions and limitations hereof and of Pipeline’s Rate Schedule FTS,
Pipeline agrees to transport and deliver to or for Customer at the Point(s) of Delivery and
Customer agrees to accept or cause acceptance of delivery of the quantities of natural gas
received by Pipeline on any day pursuant to Paragraph 1.1 above, less the applicable Fuel
Reimbursement Quantities; provided, however, Pipeline shall not be obligated to deliver at
any Point of Delivery on any day a quantity of natural gas in excess of the applicable MDQ
set forth on Exhibit B for each such Point of Delivery or Customer’s nomination, if less than
the MDQ.

 

 

FTS Contract No. 71658

	1.3	 	To the extent permitted by Pipeline’s FERC Gas Tariff, Fifth Revised Volume No. 1
(hereinafter the “Tariff”), and FERC orders and regulations, Pipeline shall have the right to
interrupt service under this Agreement if at any time Customer fails to materially comply with
any provision of this Agreement.

ARTICLE II

TERM OF AGREEMENT

	2.1	 	This Agreement shall become effective as of the date first set forth hereinabove written
and shall continue through August 31, 2013 (the “Primary Term”). Thereafter, this Agreement
shall continue for successive terms of twelve (12) months each (the “Renewal Term”) unless
either party gives ninety (90) days written notice to the other party prior to the end of the
Primary Term or any twelve (12) month Renewal Term thereafter.
	 
	2.2	 	Termination of this Agreement shall not affect or cancel the obligations, claims, and
liabilities then owing by either party to the other.
	 
	2.3	 	Pipeline’s or Customer’s right to terminate this Agreement upon expiration of the Primary
Term hereof shall be subject to the pregranted abandonment provision of Section 7 of the
General Terms and Conditions of the Tariff.

ARTICLE III

RATE SCHEDULE

	3.1	 	Customer shall pay Pipeline each month for service provided under this Agreement the
maximum rates and such other charges as are specified in the Tariff for Rate Schedule FTS,
including but not limited to the Annual Charge Adjustment (ACA), the Fuel Reimbursement
Charge, Electronic Bulletin Board charges, and penalties.
	 
	3.2	 	Pursuant to Rate Schedule FTS of the Tariff, Pipeline may agree from time to time to collect
a rate lower than the maximum rate set forth in the Tariff. Such a discounted rate shall be
set forth in Exhibit D or in a separate written agreement.
	 
	3.3	 	The rates and charges provided for under Rate Schedule FTS shall be subject to increase or
decrease pursuant to any order issued by the Federal Energy Regulatory Commission in any
proceeding initiated by Pipeline or applicable to the services performed hereunder. Customer
agrees that Pipeline shall, without any further agreement by Customer, have the right to
change from time to time, all or any part of this Agreement, as well as all or any part of
Rate Schedule FTS, or the General Terms and Conditions thereof, including without limitation
the right to change the rates and charges in effect hereunder, pursuant to Section 4(d) of
the Natural Gas Act as may be deemed necessary by Pipeline, in its reasonable judgment, to
assure just and reasonable service and rates under the Natural Gas Act. Nothing contained
herein shall prejudice the rights of Customer to contest at any time the changes made pursuant
to this Paragraph 3.3, including the right to

 

 

FTS Contract No. 71658

contest the transportation rates or charges for the services provided under this Agreement,
from time to time, in any subsequent proceeding.

ARTICLE IV

POINT(S) OF RECEIPT AND DELIVERY

	4.1	 	Natural gas to be received by Pipeline from or for Customer hereunder shall be delivered
at the outlet side of the measuring station(s) at the Point(s) of Receipt set forth in
Exhibit A of this Agreement, with the Maximum Daily Quantity and the pressure obligation
indicated for each such Point of Receipt.
	 
	4.2	 	Natural gas to be delivered by Pipeline to or for Customer hereunder shall be delivered at
the outlet side of the measuring station(s) at the Point(s) of Delivery set forth in Exhibit
B of this Agreement, with the Maximum Daily Quantity and the pressure obligation indicated for
each such Point of Delivery.

ARTICLE V

CONDITIONS OF SERVICE

	5.1	 	This Agreement and all terms and provisions contained or incorporated herein are subject
to Rate Schedule FTS and the General Terms and Conditions of the Tariff on file with the
Federal Energy Regulatory Commission, or other duly constituted authorities having
jurisdiction, and as the same may be legally amended or superseded, which rate schedule and
General Terms and Conditions are incorporated by reference and made a part of this Agreement.
Capitalized terms herein shall have the meaning assigned to such terms in the Tariff. In the
event of conflict between this Agreement and Pipeline’s Tariff, the Tariff shall control.
	 
	5.2	 	For service hereunder which is subject to 18 C.F.R Section 284.101 (Section 311
transportation), Customer must execute Exhibit C and the affidavits attached thereto, all of
which are hereby incorporated by reference and made a part of this Agreement.
	 
	5.3	 	The parties hereto agree that neither party shall be liable to the other for any special,
indirect, or consequential damages (including business interruptions) arising out of or in any
manner related to this Agreement.

ARTICLE VI

NOTICES

Except as herein otherwise provided or as provided in the General Terms and Conditions of
the Tariff, any notice, request, demand, statement, bill or payment provided for in this
Agreement, or any notice which any party may desire to give to the other, shall be in
writing and shall be considered as duly delivered when received by registered, certified,
or first class mail, or overnight delivery service (Federal Express, UPS, or U.S. Postal
Service) at the address of the parties as follows:

 

 

FTS Contract No. 71658

	 	 	 

	(a) Pipeline:

	 	ENBRIDGE PIPELINES (MIDLA) L.L.C.
	 

	 	Attn: Contract Administration
	 

	 	1100 Louisiana, Suite 3300
	 

	 	Houston, Texas 77002
	 
	 	 
	 

	 	Telephone No. (713) 821-2000
	 

	 	Facsimile No. (713) 821-3313
	 
	 	 
	(b) Customer:

	 	Enbridge Marketing (US), LP
	 

	 	Attention: Mr. Robert Hall
	 

	 	1100 Louisiana, Suite 3600
	 

	 	Houston, Texas 77002

or such other address as either party shall subsequently designate by formal written notice.

ARTICLE VII

MISCELLANEOUS

	7.1	 	This Agreement constitutes the entire agreement between the parties and no modification,
waiver, representation or agreement, oral or otherwise, shall affect the subject matter hereof
unless and until such modification, waiver, representation or agreement is reduced to writing
and executed by authorized representatives of the parties. No waiver by either Customer or
Pipeline of the performance of any of the provisions of this Agreement by the other or the
failure to exercise the rights granted to either Customer or Pipeline herein s shall operate
or be construed as an implied or express waiver of any future performance by the other party,
or right of Customer or Pipeline herein, whether of a like or of a different character.
	 
	7.2	 	This Agreement shall be binding upon and inure to the benefit of the successors and assigns
of each of the parties hereto.
	 
	7.3	 	The interpretation and performance of this Agreement shall be in accordance with the laws of
the State of Texas, excluding conflicts of law principles that would require the application
of the laws of a different jurisdiction.
	 
	7.4	 	As this Firm Transportation Agreement relates to Capacity Release, the Replacement Shipper
grants to Midla its permission and approval to notify the Releasing Shipper (even when such
Releasing Shipper is an Energy Affiliate of Midla) of certain credit-related information
specified under Section 4.12(c) of the General Terms and
Conditions of Midla’s FERC Gas
Tariff.
	 
	7.5	 	When this Agreement becomes effective, it shall supersede the following agreements between
the parties hereto:

	 	 	 	 	 

	 
	 	Dated	 	N/A
	 
	 
	 	Dated	 	N/A

 

 

FTS Contract No. 71658

IN WITNESS WHEREOF, the parties hereto have caused this Agreement to be signed by their respective
agents thereunto duly authorized, the day and year first above written.

ENBRIDGE PIPELINES (MIDLA) L.L.C.

	 	 	 	 	 	 	 	 	 

	ATTEST:	 	 	 	 	 	 
	 
	 	 	 	 	 	 	 	 
	By:

	 	/s/ Angela H. Byrd
	 	 	 	By:
	 	/s/ Stephen L. Merritt
	 

	 	 
	 	 	 	 	 	 
	Angela H. Byrd         Contract Administrator	 	 	 	Stephen L. Merritt                
           Vice President 
	(Printed Name)         (Title)	 	 	 	(Printed
Name)                                             (Title)
	 
	 	 	 	 	 	 	 	 
	 

	 	 	 	 	 	CUSTOMER

	 
	 	 	 	 	 	 	 	 
	ATTEST: 
	 	 	 	 	 	 
	 
	 	 	 	 	 	 	 	 
	By:

	 	/s/ Bob Hall	 	 	 	By:
	 	/s/ Janet Loy
	 

	 	 
	 	 	 	 	 	 
	Bob Hall	 	 	 	Janet Loy         
                    
               
          President
	(Printed Name)                                     (Title)	 	 	 	(Printed
Name)                                                       (Title)

 

 

FTS Contract No. 71658

SERVICE AGREEMENT

(APPLICABLE TO RATE SCHEDULE FTS)

EXHIBIT A

To the Agreement under Rate Schedule FTS between Enbridge Pipelines (Midla) L.L.C. (Pipeline) and
Enbridge Marketing (US), LP (Customer) concerning Point(s) of Receipt.

Point(s) of Receipt

          Dated: September 1, 2008

	 	 	 	 	 	 	 	 	 	 	 	 	 
	 	 	 	 	 	 	 	 	 	 	Maximum Receipt
	primary
point
	 	 	Maximum Daily	 	Pressure
	Of
Receipt
	 	 	Receipt Obligation	 	(psig)
	178 (Oak Hill)
	 	Jan-March	 	 	500	 	 	 	350	 
	 
	 	April	 	 	250	 	 	 	 	 
	 
	 	May-Sept	 	 	175	 	 	 	 	 
	 
	 	Oct	 	 	250	 	 	 	 	 
	 
	 	Nov-Dec	 	 	500	 	 	 	 	 
	 
	 	 	 	 	 	 	 	 	 	 	 	 
	179 (Siegan Lane)
	 	Jan-March	 	 	8,300	 	 	 	800	 
	 
	 	April	 	 	4,150	 	 	 	 	 
	 
	 	May-Sept	 	 	2,950	 	 	 	 	 
	 
	 	Oct	 	 	4,150	 	 	 	 	 
	 
	 	Nov-Dec	 	 	8,300	 	 	 	 	 
	 
	 	 	 	 	 	 	 	 	 	 	 	 
	180 (Hammond Hwy)
	 	Jan-March	 	 	7,500	 	 	 	800	 
	 
	 	April	 	 	3,750	 	 	 	 	 
	 
	 	May-Sept	 	 	2,625	 	 	 	 	 
	 
	 	Oct	 	 	3,750	 	 	 	 	 
	 
	 	Nov-Dec	 	 	7,500	 	 	 	 	 
	 
	 	 	 	 	 	 	 	 	 	 	 	 
	181 (Highland Rd)
	 	Jan-March	 	 	3,700	 	 	 	800	 
	 
	 	April	 	 	1,850	 	 	 	 	 
	 
	 	May-Sept	 	 	1,295	 	 	 	 	 
	 
	 	Oct	 	 	1,850	 	 	 	 	 
	 
	 	Nov-Dec	 	 	3,700	 	 	 	 	 
	 
	Secondary Point of 	 	Maximum Daily Receipt	 	Maximum Receipt
	Receipt
	 	 Obligation	 	Pressure
	 
	ALL
	 	N/A	 	Midla’s maximum

allowable operating

pressure at point

	 	 	 

	Signed for Identification
	 	 
	 
	 	 
	Enbridge Pipelines (Midla) L.L.C.:

	 	/s/ Stephen L. Merritt
	 
	 	 
	Customer:

	 	/s/ Janet Loy
	 
	 	 
	Supersedes Exhibit A Dated:

	 	N/A

 

 

FTS Contract No. 71658

SERVICE AGREEMENT

(APPLICABLE TO RATE SCHEDULE FTS)

EXHIBIT B

To the Agreement under Rate Schedule FTS between Enbridge Pipelines (Midla) L.L.C. (Pipeline)
and Enbridge Marketing (US), LP (Customer) concerning Point(s) of Delivery.

Point(s) of Delivery

          Dated: September 1, 2008

	 	 	 	 	 	 	 	 	 	 	 	 	 
	 	 	 	 	 	 	 	 	 	 	Maximum Delivery
	Primary
Point
	 	 	Maximum Daily	 	Pressure
	Of
Delivery
	 	 	Delivery Obligation	 	(psig)
	8030 (Oak Hill)
	 	Jan-March	 	 	500	 	 	 	100	 
	 
	 	April	 	 	250	 	 	 	 	 
	 
	 	May-Sept	 	 	175	 	 	 	 	 
	 
	 	Oct	 	 	250	 	 	 	 	 
	 
	 	Nov-Dec	 	 	500	 	 	 	 	 
	 
	 	 	 	 	 	 	 	 	 	 	 	 
	8021 (Siegan Lane)
	 	Jan-March	 	 	8,300	 	 	 	100	 
	 
	 	April	 	 	4,150	 	 	 	 	 
	 
	 	May-Sept	 	 	2,950	 	 	 	 	 
	 
	 	Oct	 	 	4,150	 	 	 	 	 
	 
	 	Nov-Dec	 	 	8,300	 	 	 	 	 
	 
	 	 	 	 	 	 	 	 	 	 	 	 
	8073 (Hammond Hwy)
	 	Jan-March	 	 	7,500	 	 	 	150	 
	 
	 	April	 	 	3,750	 	 	 	 	 
	 
	 	May-Sept	 	 	2,625	 	 	 	 	 
	 
	 	Oct	 	 	3,750	 	 	 	 	 
	 
	 	Nov-Dec	 	 	7,500	 	 	 	 	 
	 
	 	 	 	 	 	 	 	 	 	 	 	 
	8056 (Highland Rd)
	 	Jan-March	 	 	3,700	 	 	 	100	 
	 
	 	April	 	 	1,850	 	 	 	 	 
	 
	 	May-Sept	 	 	1,295	 	 	 	 	 
	 
	 	Oct	 	 	1,850	 	 	 	 	 
	 
	 	Nov-Dec	 	 	3,700	 	 	 	 	 
	 
	Secondary Point of 	 	Maximum Daily Delivery	 	Maximum Delivery
	Delivery
	 	 Obligation	 	Pressure
	 
	ALL
	 	N/A	 	Midla’s maximum

allowable operating

pressure at point

	 	 	 

	Signed for Identification
	 	 
	 
	 	 
	Enbridge Pipelines (Midla) L.L.C.:

	 	/s/ Stephen L. Merritt
	 
	 	 
	Customer:

	 	/s/ Janet Loy
	 
	 	 
	Supersedes Exhibit A Dated:

	 	N/A

 

 

FTS Contract No. 71658

SERVICE AGREEMENT

(APPLICABLE TO RATE SCHEDULE FTS)

EXHIBIT C

To the Agreement under Rate Schedule FTS between Enbridge Pipelines (Midla) L.L.C. (Pipeline) and
Enbridge Marketing (US), LP (Customer) concerning “on behalf of” entity(ies).

“On Behalf of” Entity(ies)

          Dated: N/A

	 	 	 

	Name
	 	Type
	 	 	 
	 
	 	 
	 
	 	 	 
	 
	 	 
	 
	 	 	 
	 
	 	 

Customer warrants that the transportation by Pipeline hereunder will be “on behalf of” the above
listed entity(ies) and in full compliance with Section 311 of the Natural Gas Policy Act of 1978
(NGPA) and FERC Order No. 525 et seq. Customer shall indemnify and hold Pipeline harmless from any
and all liability arising from any acts and omissions or material representations of Customer in
connection with or related to Pipeline’s service under Section 311 of the NGPA. Customer shall not
cause gas to be delivered to Pipeline for transportation “on behalf of” any other entity until such
time as this Exhibit C has been amended to reflect the addition of such entity.

	 	 	 

	Signed for Identification
	 	 
	 
	 	 
	Enbridge Pipelines (Midla) L.L.C.:

	 	/s/ Stephen L. Merritt
	 
	 	 
	Customer:

	 	/s/ Janet Loy
	 
	 	 
	Supersedes Exhibit C Dated:

	 	N/A

 

 

FTS Contract No. 71658

SERVICE AGREEMENT

(APPLICABLE TO RATE SCHEDULE FTS)

EXHIBIT D

To the Agreement under Rate Schedule FTS between Enbridge Pipelines (Midla) L.L.C. (Pipeline) and
Enbridge Marketing (US), LP (Customer) concerning discount information.

Discount Information

Dated: September 1, 2008

Discounted Transportation Rate: $2.00 — Discount applies only to reservation rate. All other rate
and charges apply as specified in the tariff.

	 	 	 	 	 
	Discounted Rate Effective:
	 	From: September 1, 2008
	 	To: August 31, 2013

	 	 	 

	___ Evergreen:

	 	___ Year-to-Year
	 

	 	___ Month-to-Month

Condition for Discounted Transportation Rate (check applicable condition(s)):

	 	þ	 	Discounted Transportation Rate applicable to specified
quantities under Shipper’s Service Contract(s):

	 	 	 	 	 	 	 

	January
	 	 	20,000	 	 	MMBtu
	February
	 	 	20,000	 	 	MMBtu
	March
	 	 	20,000	 	 	MMBtu
	April
	 	 	12,000	 	 	MMBtu
	May
	 	 	7,700	 	 	MMBtu
	June
	 	 	7,700	 	 	MMBtu
	July
	 	 	7,700	 	 	MMBtu
	August
	 	 	7,700	 	 	MMBtu
	September
	 	 	7,700	 	 	MMBtu
	October
	 	 	12,000	 	 	MMBtu
	November
	 	 	20,000	 	 	MMBtu
	December
	 	 	20,000	 	 	MMBtu

	 	o	 	Discounted Transportation Rate applicable to specified
quantities above or below a certain level or all quantities if quantities
exceed a certain level:

Discounted Transportation Rate applicable to                      

MMBtu above/below                      MMBtu

or

	 	o	 	Discounted Transportation Rate applicable in a specified
relationship to quantities actually transported:

 

 

FTS Contract No. 71658

Adjustment in Transportation Rate:                      

(based on                      MMBtu actually transported)

	 	o	 	Discounted Transportation Rate applicable to specified
quantities during specified periods of time or during specified periods of
the year:

                     MMBtu for the following time period(s):

	 	o	 	Discounted Transportation Rate applicable to specified
quantities at specific Point(s) of Receipt or Point(s) of Delivery or other
geographical locations:

Point(s) of Receipt:                     

Point(s) of Delivery:                     

Other geographical locations:                     

	 	o	 	Discounted Transportation Rate applicable to production
reserves committed or dedicated by Shipper:

Production Reserves:                      Field

	 	o	 	Discounted Transportation Rate based on published index
prices for specific Point(s) of Receipt and/or Point(s) of Delivery or
other agreed-upon published pricing reference points (based upon the
differential between published prices or arrived at by formula):

Index Price(s):                                         

  _________________

____ Differential between Index Prices 

or

____ Formula:                                         

In no event shall the discounted rate established as set forth above exceed the otherwise
applicable maximum lawful rate.

	 	 	 

	Signed for Identification
	 	 
	 
	 	 
	Enbridge Pipelines (Midla) L.L.C.:

	 	/s/ Stephen L. Merritt
	 
	 	 
	Customer:

	 	/s/ Janet Loy
	 
	 	 
	Supersedes Exhibit D Dated:

	 	N/Aexv10w23

Exhibit 10.23

GAS PROCESSING AGREEMENT

TOCA GAS PROCESSING PLANT

ST. BERNARD PARISH, LOUISIANA

BETWEEN

AMERICAN MIDSTREAM, LLC

(PLANT SUPPLIER)

AND

ENTERPRISE GAS PROCESSING, LLC

(PROCESSOR)

JULY 1, 2010

			
	 	 	 
	L1167
	 	Execution Copy

 

 

GAS PROCESSING AGREEMENT

TOCA GAS PROCESSING PLANT

ST. BERNARD PARISH, LOUISIANA

TABLE OF CONTENTS

	 	 	 	 	 
	ARTICLES	 	PAGE NUMBER
	Article I — Definitions
	 	 	2	 
	 
	Article II — Exhibits
	 	 	6	 
	 
	Article III — Capacity of Plant
	 	 	6	 
	 
	Article IV — Delivery and Redelivery of Plant Supplier’s Gas
	 	 	7	 
	 
	Article V — Allocation of Products
	 	 	9	 
	 
	Article VI — Consideration Due Plant Supplier
	 	 	14	 
	 
	Article VII — Plant Volume Reduction and Bypassed Gas
	 	 	14	 
	 
	Article VIII — Term
	 	 	17	 
	 
	Article IX — Payment of Royalty and Taxes
	 	 	18	 
	 
	Article X — Laws, Regulations and Force Majeure
	 	 	18	 
	 
	Article XI — Notices
	 	 	19	 
	 
	Article XII — Indemnification
	 	 	20	 
	 
	Article XIII — Miscellaneous
	 	 	21	 

EXHIBITS

“A” — Example Calculation — Product Allocation Procedure

“B” — Example Calculation — Plant Volume Reduction

“C” — Fractionation Fee

“D” — Product Index Bases

“E” — “Plant Supplier’s Fields for Processing”

“F” — Settlement Instructions

2

 

GAS PROCESSING AGREEMENT

TOCA GAS PROCESSING PLANT

ST. BERNARD PARISH, LOUISIANA

     THIS GAS PROCESSING AGREEMENT (the “Agreement”), is made and entered into this 1st day of
July 2010 (the “Effective Date”), by and between AMERICAN MIDSTREAM, LLC (“Plant Supplier”) and
ENTERPRISE GAS PROCESSING, LLC, (“Processor”).

R E C I T A L S

     A. WHEREAS, Processor has constructed the Toca Gas Processing Plant on a tract of land in
Sections 54 and 55, T-14-S, R-4-E, St. Bernard Parish, Louisiana (herein called the “Toca Plant” or
“Plant”), and operates said Plant for the purpose of extracting Liquid Hydrocarbons, as hereinafter
defined, from certain gas delivered to the Plant from the pipeline system of Southern Natural Gas
Company (herein called “Southern’s Lines”); and

     B. WHEREAS, the Toca Plant Owners have heretofore individually entered into an agreement with
Enterprise Products Operating LLC, by and through its predecessor in interest, Shell Oil Company,
as Owner of the Norco Fractionation Plant, entitled “Hydrocarbon Fractionation Agreement” (herein
called “Fractionation Agreement”), whereby the Toca Plant Operator will deliver for the account of
Plant Owners Raw Make, as hereinafter defined, recovered at the Toca Plant to Fractionator for
transportation to the Norco Fractionation Plant and for fractionation into commercial Products; and

     C. WHEREAS, Plant Supplier owns or holds the gas processing rights to gas produced from the
lands and leases as set out on Exhibit “E”, attached hereto and incorporated herein by reference,
and has the right to extract or have extracted the Liquid Hydrocarbons from such gas, which gas
will be transported through Southern’s Lines to the Plant for Plant Supplier’s account; and

     D. WHEREAS, Processor and Plant Supplier desire hereby to provide the terms and conditions
under which such gas will be delivered from Southern’s Lines to the Plant pursuant to the
Transportation Agreement, as hereinafter defined, for processing for Plant Supplier’s account and

			
	 	 	 
	L1167	 	 
	American Midstream, LLC
	 	Execution Copy

1

 

the Liquid Hydrocarbons in such gas will be sold to Processor at the Plant Delivery Point for
a consideration to Plant Supplier consisting of a share of Products, all as hereinafter more fully
set forth;

     NOW, THEREFORE, in consideration of the premises and of the mutual covenants and agreements
herein provided, the parties hereto agree as follows:

ARTICLE I — DEFINITIONS

     1.1 Definitions. The following definitions of terms shall apply for all purposes of
this agreement, including the preambles and exhibits, unless the context otherwise clearly
requires.

     1.1.1 The term “gas” shall mean all vaporized hydrocarbons and vaporized concomitant
materials, whether produced with oil or from gas or gas condensate wells.

     1.1.2 A “cubic foot of gas” shall mean the volume of gas contained in one cubic foot
of space at a standard pressure base and a standard temperature base. The standard pressure base
shall be 15.025 pounds per square inch absolute, and the standard temperature base shall be 60
degrees Fahrenheit. Whenever the conditions of pressure and temperature differ from the above
standard, conversion of the volume from these conditions to the standard conditions shall be made
in accordance with the Ideal Gas Laws, corrected for deviation by the methods set forth in the
American Gas Association Measurement Committee Report No. 3 dated April 1955, as said report may be
amended from time to time. The terms “MCF” and “MMCF” shall relate, respectively, the 1,000 cubic
feet of gas and 1,000,000 cubic feet of gas.

     1.1.3 “Bypassed Gas” shall mean gas which has been delivered to Plant Owners at the
Plant Delivery Point, but which has been returned to Southern at the Plant Redelivery Point without
having been processed.

     1.1.4 “Committed Gas” shall mean the gas produced by a Plant Owner which has been
committed to and made available for processing in the Toca Plant by virtue of such Plant Owner’s
ownership of capacity in the Plant under the provisions of the Construction and Operating
Agreement.

			
	 	 	 
	L1167	 	 
	American Midstream, LLC
	 	Execution Copy

2

 

     1.1.5 “Construction and Operating Agreement” shall mean that certain agreement
entitled “Agreement for the Construction and Operation of the Toca Gas Processing Plant, St.
Bernard Parish, Louisiana”, entered into effective as of July 1, 1970 by Plant Owners to provide
for the construction, ownership and operation of the Toca Plant.

     1.1.6 “Determined Plant Capacity” shall mean the gas handling capacity of the Plant
at design recovery levels, which currently is deemed to be 1030.0 MMCF/D, but the Plant gas
handling capacity and/or liquid recovery levels shall be subject to revision from time to time by
Plant Owners to reflect Plant capacity; provided that in any such adjustment the gas handling
capacity shall never be adjusted below 1030.0 MMCF/D, nor shall it be determined to be greater, at
normal recovery levels of 90 percent propane, than 80 percent of the maximum gas handling capacity
of the Plant at a delivery pressure of 800 psia and with a Plant pressure loss not to exceed 35
psi.

     1.1.7 “Field Delivery Point” shall mean any point at which gas being transported in
Southern’s Lines and subject to processing in the Plant is initially measured for the purpose of
delivery for sale or for transportation.

     1.1.8 “Fractionator” shall mean Enterprise Products Operating LLC in its capacity as
owner and operator of the Norco Fractionation Plant and related pipelines and facilities.

     1.1.9 “Fractionation Expense” shall mean the fractionation expense calculated per the
terms and conditions of Exhibit “C.”

     1.1.10 “Gallon” shall mean a standard U.S. liquid gallon of 231 cubic inches when said
liquid has a temperature of 60 degrees Fahrenheit and is at a pressure sufficient for
liquification.

     1.1.11 “Gas Transporter” shall mean the party or parties who transport the gas
produced from the respective Exhibit “E” field or fields from time to time.

     1.1.12 “Gross Receipts” shall mean the monthly revenue calculated from the value of
the individual Products (expressed in cents per gallon) multiplied by the volume of the Products
allocated to the Plant Supplier. The value of each individual Product shall be based on the pricing

			
	 	 	 
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basis set forth under Exhibit “D”, as such pricing basis may change from time to time as
provided in Exhibit C.

     1.1.13 “Inert Constituents” shall mean non-hydrocarbon constituents contained in Gas,
including, without limitation, carbon dioxide, water vapor, ozone, nitrous oxide, and mercury,
but, for the avoidance of doubt, expressly excluding NGLs.

     1.1.14 “Liquid Hydrocarbons”, sometimes herein used to refer to liquefiable
hydrocarbons present in the gas stream and sometimes herein used to refer to hydrocarbons in a
liquid state after extraction by the Plant from the gas stream, shall in either case mean natural
gasoline (iso-pentanes plus heavier hydrocarbons), butanes, propane and ethane.

     1.1.15 “Net Proceeds” shall mean the Gross Receipts obtained from the sale of the
share of Products to which Plant Supplier is entitled under this Agreement when Plant Operator
under the terms of this Agreement is authorized to make such sale, less the following costs and
expenses: (a) excise, sales, use, severance, gathering, processing, fuel use, or other similar
taxes (reference Article IX.3) imposed by any taxing authority having or asserting jurisdiction
over the production, sale or use of the Products and which tax Processor is obligated to pay; (b)
actual tank car expense if the Product is shipped in tank cars, and rail transportation and/or
other rail carrier costs if incurred by Processor; (c) actual other transportation costs if
incurred by Processor, and (d) the Fractionation Expense.

     1.1.16 “Plant Delivery Point” shall mean the point on Southern’s Lines at which gas
is delivered by Southern to Plant Owners for processing in the Plant.

     1.1.17 “Plant Operator” shall mean Enterprise Products Operating LLC or any successor
to Enterprise Products Operating LLC selected by Toca Plant Owners to operate the Plant.

     1.1.18 “Plant Redelivery Point” shall mean the point on Southern’s Lines at which
Residue Gas is returned by Plant Owners to Southern.

     1.1.19 “Plant Supplier” shall mean any Plant Supplier, including Plant Supplier
hereunder, whose gas is being transported through Southern’s Lines and who has entered into a Gas

			
	 	 	 
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Processing Agreement or a Products Purchase Agreement with Plant Operator to have gas
processed in the Plant. Such term shall also apply to a Plant Owner with respect to Committed Gas
made available by it for processing in the Plant in excess of 125 percent of such Owner’s capacity
in the Plant, which excess, as provided in the Construction and Operating Agreement, is considered
to be under a Products Purchase Agreement.

     1.1.20 “Products” shall mean the commercial products fractionated from the Raw Make
by Fractionator at the Norco Fractionation Plant pursuant to the terms of the Fractionation
Agreement, including, but not limited to, natural gasoline, butanes, propane and ethane (including
such methane allowable in commercial ethane), and shall include any Liquid Hydrocarbons recovered
by the inlet scrubber at the Plant for which the preferred disposition is at the Plant rather than
being combined with the Raw Make.

     1.1.21 “Raw Make” shall mean the combined stream of Liquid Hydrocarbons and
concomitant materials recovered from gas processed in the Plant and shall include any liquefied
hydrocarbons recovered by the Plant inlet scrubber if combined with the Raw Make.

     1.1.22 “Residue Gas” shall mean the stream of gas returned to Southern at the Plant
Redelivery Point after the gas received from Southern has been processed in the Plant for the
recovery of Liquid Hydrocarbons and shall include any Bypassed Gas commingled with such processed
gas.

     1.1.23 “Southern’s Lines” shall mean that portion of Southern’s gas pipeline system
upstream of the Plant Delivery Point, plus any present or future extensions or loops thereof,
which is transporting unprocessed gas for processing at the Plant site.

     1.1.24 “Toca Plant Owners” or “Plant Owners” shall mean the parties who own
the Toca Plant, whether presently or in the future.

     1.1.25 “Transportation Agreement” shall mean the applicable agreement in place from
time to time between Southern and Plant Supplier or Gas Transporter which covers the
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ARTICLE II — EXHIBITS

     2.1 Exhibits. The following exhibits are attached to and made a part of this
agreement:

     2.1.1 Exhibit “A”, which is an example calculation illustrating the procedure for
allocating Products to Plant Owners and Plant Suppliers.

     2.1.2 Exhibit “B”, which is an example calculation illustrating the procedure for
calculating and allocating Plant Volume Reduction.

     2.1.3 Exhibit “C”, which is description of the procedure for calculating the
Fractionation Expense.

     2.1.4 Exhibit “D”, which lists the Product prices.

     2.1.5 Exhibit “E”, which lists the Field Delivery Point(s) from which gas to be
processed hereunder is produced. Exhibit “D” may be amended to add additional Field Delivery Points
from time to time upon mutual agreement of Processor and Plant Supplier.

     2.1.6 Exhibit “F”, which lists the Plant Supplier’s accounts payable address for
checks or bank instructions for wire transfer, federal tax identification number, and invoice and
plant statement addresses, all of which provide the settlement instructions for the transactions
hereunder. Exhibit “E” may be amended by Plant Supplier from time to time.

ARTICLE III — CAPACITY OF PLANT

     3.1 Plant Design. The Toca Plant is designed to extract approximately 50 percent of
the ethane and over 90 percent of the propane, together with essentially all of the butanes and
heavier liquefiable hydrocarbons contained in the gas at a gas flow rate of 1030 MMCF per day, with
gas handling facilities designed to handle 1030 MMCF per day at a delivery pressure of 800 psia and
with a Plant pressure loss not to exceed 35 psi. The pressure base for the foregoing design
specifications is 14.73 pounds per square inch absolute at a temperature base of 60 degrees
Fahrenheit; however, a pressure base of 15.025 pounds psia shall be used in connection with any

			
	 	 	 
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adjustment of the Determined Plant Capacity and for determining the Plant capacity which is
owned and/or utilized by Plant Owners.

     3.2 Capacity Not Warranted. Plant Supplier hereby specifically recognizes that the
foregoing representations regarding the processing capacity of the Toca Plant are merely advisory
and do not constitute a warranty by or obligation of Processor as to capacity. Plant Supplier
further recognizes that the Determined Plant Capacity may change from time to time as the result
of operating experience or performance tests or alterations made to the Plant by Plant Owners.

ARTICLE IV — DELIVERY AND REDELIVERY OF PLANT SUPPLIER’S GAS

     4.1 Gas to be Delivered by Plant Supplier. Commencing as of the Effective Date, Plant
Supplier shall deliver to Processor at the Plant Delivery Point for processing hereunder all of
Plant Supplier’s gas delivered to the Field Delivery Point(s) listed on Exhibit “E”, less and
except Plant Supplier’s pro rata share of the gas which is used by Southern for compressor fuel,
incidental sales of gas for drilling purposes and other routine and normal uses as may be
necessary to the maintenance of leases or operation of Southern’s Lines and also any gas lost in
the normal operation of Southern’s Lines upstream of the Plant Delivery Point, including, but not
limited to, gas lost in pipeline blowdown for repairs or tie-ins, cleaning and purging and in
pipeline scrubber operations. Such deliveries of gas shall be continued hereunder during the term
hereof. The rights granted herein by Plant Supplier to Processor are exclusive, and Liquid
Hydrocarbons shall not be stripped in the field or elsewhere from Plant Supplier’s gas subject
hereto prior to delivery at the Toca Plant other than by usual field separation methods which may
include adiabatic expansion utilizing the natural pressures available from the wells, but shall
exclude facilities designed to recover Liquid Hydrocarbons including but not limited to solid bed
absorption, lean oil absorption, turbo-expander or mechanical refrigeration principles. In no
event shall Processor be liable to Plant Supplier if Southern fails for any reason to deliver
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     4.2 When Plant Supplier’s Gas is to be Bypassed. During periods when the Plant is
shut down because of mechanical failure, force majeure or necessary maintenance or repairs, all of
Plant Supplier’s gas being transported through Southern’s Lines shall be Bypassed Gas. When the
Plant is partially shut down for any of the above-mentioned reasons, or if the Plant lacks
sufficient capacity to handle all gas available for processing from Southern’s Lines, Plant
Supplier’s gas shall be processed only on a space available basis, and to the extent that gas
handling capacity in the Plant, for any reason, is not available for such gas, such gas shall be
preferentially bypassed along with the gas of any other Plant Suppliers which is made available for
processing in the Plant. All of such gas bypassed preferentially will be determined monthly on an
average daily basis and will be prorated to all Plant Suppliers under their respective agreements
in the ratio that the average daily volume of gas made available by each during the month bears to
the total average daily volumes made available by all such Plant Suppliers during the month;
provided that, if any continuous period of complete shutdown of the Plant shall equal or exceed
twelve (12) hours’ duration, the time of each such shutdown [determined to the nearest increment of
six (6) hours] and the measured (or estimated, in the absence of measurement) volumes of gas
bypassed during such determined period of shutdown shall be excluded in determining the average
volume of Plant Suppliers’ gas considered to have been bypassed during the affected month for
purposes hereof.

     4.3 Redelivery of Plant Supplier’s Gas to Southern’s Lines. After processing Plant
Supplier’s gas delivered hereunder to the Plant, Processor shall redeliver the Residue Gas to
Southern’s Lines at the Plant Redelivery Point. The Residue Gas prior to being commingled with any
Bypassed Gas shall have a total or gross heating value of not less than one thousand (1,000) BTU’s
per cubic foot (gross heating value saturated with water vapor) and shall otherwise comply with the
quality specifications enumerated in the contract heretofore executed by Plant Owners and Southern;
provided that the combined gas stream delivered by Southern at the Plant Delivery Point meets such
specifications.

     4.4 Production Estimates. Effective as of the date of this Agreement, Processor
requires from Plant Supplier five (5) days prior to the start of each month gas composition
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and monthly volume forecast, i.e. monthly wellhead production estimates, daily pipeline
nomination volume, or other delivery point information for any Gas that may be delivered into
Southern’s Lines, for each Field Delivery Point (expressed in MCF per day).

ARTICLE V — ALLOCATION OF PRODUCTS

     5.1 General. Products fractionated from the Raw Make recovered from gas processed in
the Plant shall be allocated to the source of each Plant Owner’s Committed Gas and each Plant
Supplier’s gas in accordance with the procedure set forth in the following sections of this Article
V, which procedure is illustrated by the example calculation set forth in Exhibit “A” hereto. As
shown on said Exhibit, separate calculations shall be made for each Product. For the purposes of
such allocations, Plant Supplier under this Agreement shall be allocated Products on the same basis
as Products are allocated to Plant Owners. Processor will respond promptly to inquiries from Plant
Supplier regarding daily operating rates and daily production rates at the Plant.

     5.2 “Plant Supplier’s Inert Constituents” Plant Supplier shall retain title to all
Inert Constituents in the Natural Gas delivered by Plant Supplier under this Agreement
(collectively, whether removed from the Natural Gas or not, “Plant Supplier’s Inert
Constituents”), including but not limited to, carbon dioxide (CO2). To the extent that
Processor removes Plant Supplier’s Inert Constituents from such Natural Gas and Plant Supplier has
not made arrangements to utilize, market or dispose of Plant Supplier’s Inert Constituents,
Processor may, but is not required to, dispose of some or all of Plant Supplier’s Inert
Constituents by venting or other methods. If (i) venting Plant Supplier’s Inert Constituents is
ever prohibited or disallowed for any reason or is deemed by Processor to be uneconomic, or (ii)
additional costs are required to vent, dispose of or handle Plant Supplier’s Inert Constituents due
to new rules, regulations or other laws, then Plant Supplier shall promptly (i) make alternate
arrangements to utilize, market and/or dispose of Plant Supplier’s Inert Constituents at Plant
Supplier’s sole cost and expense, (ii) notify Processor in writing and in reasonable detail of such
alternate arrangements, and (iii) reimburse Processor for any costs incurred by Processor for
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utilization, marketing and/or disposal. If Plant Supplier fails to comply with Plant
Supplier’s obligations under the immediately preceding sentence, Processor shall be entitled,
without further notice to Plant Supplier, to make arrangements for utilization, marketing and/or
disposal of some or all of Plant Supplier’s Inert Constituents for Plant Supplier’s account and at
Plant Supplier’s sole cost and expense; and Plant Supplier shall promptly reimburse Processor upon
demand for any costs and expenses incurred by Processor in connection with such arrangements by
Processor. PLANT SUPPLIER HEREBY RELEASES, INDEMNIFIES, DEFENDS AND HOLDS HARMLESS PROCESSOR AND
PROCESSOR’S DIRECTORS, OFFICERS, EMPLOYEES, AGENTS, AND CONTRACTORS FROM AND AGAINST ANY AND ALL
CLAIMS, DEMANDS, DAMAGES, LIABILITIES, EXPENSES, ACTIONS, CAUSES OF ACTION, LIABILITIES, LOSSES,
TAXES, PENALTIES AND FEES ARISING OUT OF OR IN ANY WAY RELATING TO (I) ANY OR ALL OF PLANT
SUPPLIER’S INERT CONSTITUENTS, INCLUDING, WITHOUT LIMITATION, THE UTILIZATION, MARKETING OR
DISPOSAL THEREOF, AND/OR (II) ANY PERSONAL INJURY, DEATH, PROPERTY DAMAGE, ENVIRONMENTAL DAMAGE,
POLLUTION, OR CONTAMINATION ARISING OUT OF OR RELATING TO ANY OR ALL OF PLANT SUPPLIER’S INERT
CONSTITUENTS.

     If any Taxes (as defined in Section 9.2), fees or other impositions are ever imposed on Plant
Supplier’s Inert Constituents and/or the utilization, marketing or disposal thereof, Plant Supplier
shall promptly pay such Taxes. If such Taxes must be paid by Processor, Plant Supplier shall
promptly reimburse Processor for any and all such Taxes paid by Processor with respect to any or
all of Plant Supplier’s Inert Constituents. If Processor is required by applicable law to pay such
Taxes on any or all of Plant Supplier’s Inert Constituents and it is unlawful for Plant Supplier to
make such reimbursement to Processor for such Taxes, Plant Supplier and Processor shall promptly
negotiate and execute an amendment to this Agreement which restores to Processor the same economic
bargain as would have resulted if Plant Supplier, rather than Processor, had paid all Taxes on
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promptly enter into such an amendment reasonably acceptable to Processor, Processor shall have
the option, exercisable in Processor’s sole discretion, to terminate this Agreement by written
notice to Plant Supplier.

     5.3 Basic Allocation Data. The volumes of gas which shall be credited as having been
processed in the Plant shall be the sum of all volumes of gas delivered to Southern at the various
Field Delivery Points, less the volumes deducted pursuant to Section 5.5 hereof. Representative
determinations for Liquid Hydrocarbons content of the gas shall be made of the gas streams at each
Field Delivery Point by Plant Operator quarterly or more often if found necessary, by
chromatographic analysis or by some other acceptable method for testing gas for Liquid Hydrocarbons
content. Plant Operator shall give Plant Supplier reasonable advance notice of tests to determine
Liquid Hydrocarbons content of the gas at the Field Delivery Point(s) for Plant Supplier’s account
so that Plant Supplier may witness such tests if desired. Plant Supplier agrees that the gas
stream(s) made available for these tests shall be representative of the stream(s) normally
delivered at the Field Delivery Point(s) for Plant Supplier’s account and will be at as near
average delivery conditions and volumes as possible at the time. Plant Operator or Plant Supplier
may request a retest if dissatisfied with the results of a particular test. If the request for a
retest is made by Plant Supplier and the Liquid Hydrocarbons content of the previous test is
confirmed within ten percent (10%), the expense of the retest shall be borne by Plant Supplier.

     5.4 Allocation of Products to the Respective Field Delivery Points. Such aforesaid
volumes of gas which are credited as having been processed and the theoretical Liquid Hydrocarbons
content of such gas at the respective Field Delivery Points shall be used as the basis for
allocating each Product fractionated from the Raw Make to such Field Delivery Points by the method
illustrated in Exhibit “A”. Such method contemplates that the volume of theoretical Liquid
Hydrocarbons (separately for each Product) for each such Field Delivery Point will be calculated by
multiplying the volume of gas credited as having been processed from such Field Delivery Point by
the theoretical Liquid Hydrocarbons content (separately as to each Product) at each such Field
Delivery Point. The total of each such Product fractionated from the Raw Make will, in turn, be

			
	 	 	 
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allocated to such respective Field Delivery Points in the ratio that the volume of theoretical
Product calculated for each Field Delivery Point bears to the sum of the volumes of such
theoretical Product calculated for all such Field Delivery Points. Any Liquid Hydrocarbons
recovered by the Plant inlet scrubber for which the preferred disposition is at the Plant rather
than being combined with the Raw Make, shall be allocated to the Field Delivery Points in the same
proportions as natural gasoline Product is allocated.

     5.5 Field Volume Statements and Sub-Allocations at Field Delivery Points. As soon as
practicable, but no later than the twentieth (20th) day of each month, Plant Supplier shall
furnish, or cause to be furnished, to Plant Operator a gas purchase statement by Gas Transporter or
such other statement as Plant Operator may reasonably require, to show the volume of gas delivered
during the preceding month from each of the Field Delivery Points for Plant Supplier’s account.
Additionally, by the twentieth (20th) day of each such month, but only when gas owned by more than
one Plant Supplier (including for Plant Supplier’s account) has been delivered through a single
Field Delivery Point, Plant Supplier, if so situated, shall furnish or cause the operator of the
Field Delivery Point to furnish to Plant Operator written instructions on sub-allocating the gas
delivered through said Field Delivery Point and Products attributable thereto for such preceding
month. Plant Operator shall be entitled to rely on the information thus furnished or caused to be
furnished in sub-allocating the Products recovered and allocated to the particular Field Delivery
Point.

     5.6 Pipeline Uses and Losses. From the quantities of gas measured at the respective
Field Delivery Points as provided above, there shall be deducted any gas which may be lost, used or
sold by Southern at any place on Southern’s Lines between such Field Delivery Points and the Plant
Delivery Point, as more specifically set forth in Section 4.1 above. It is agreed that the volumes
of such gas and the nature of each disposition, as reported by Southern to Plant Operator, shall be
subtracted by Plant Operator from the quantities of gas measured at the Field Delivery Points. In
making settlements hereunder, Plant Operator shall be entitled to rely upon the accuracy of such
information as reported to it by Southern, but Plant Operator shall footnote settlement data
supplied to the affected Plant Suppliers, noting the allocable amount of gas lost, used or sold by
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is understood that the aforesaid volumes of gas lost, used or sold by Southern at any place on
Southern’s Lines shall be allocated to all Field Delivery Points serving Southern’s Lines
(including those Field Delivery Points serving the Lines from which gas will be processed in plants
other than the Toca Plant) in the ratio which the volume of gas measured at each such Field
Delivery Point during a month bears to the total volume of gas measured at all Field Delivery
Points serving Southern’s Lines during the month.

     5.7 Product Allocation Statements. By the end of the month in which the information
referred to in the preceding two sections is received, Plant Operator shall furnish a statement to
all Plant Owners and Plant Suppliers accounting for the volume of gas delivered from each Field
Delivery Point for the preceding month together with the amount of each individual Product
allocated to said gas.

     5.8 Measurement of Field Volumes. All gas delivered at a Field Delivery Point shall be
measured by a suitable orifice meter or meters of standard make furnished, installed, operated and
kept in repair by the owners of the equipment at the point where delivery is made to Southern’s
Lines which shall be the same meter or meters used under the provisions of each Plant Owner’s or
Plant Supplier’s individual gas purchase contract with Gas Transporter. The volumes measured by
said meter or meters shall be used for purposes of settlement under this agreement. The computation
of all gas volumes measured by orifice meters shall be based on the latest orifice factors
published by the American Gas Association corrected to a base pressure of 15.025 pounds per square
inch absolute and at a base temperature of sixty degrees Fahrenheit (60°F), and the measurement
procedures, technical requirements and standards for all such meters shall be as set out in each
Owner’s or Plant Supplier’s gas purchase contract with its respective Gas Transporter. Plant
Supplier agrees that the Plant Operator shall have the right to witness all tests of the meters and
other equipment employed to measure volumes of gas delivered to Gas Transporter, and upon request,
Plant Supplier shall give Plant Operator reasonable advance notice of all such tests.

			
	 	 	 
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ARTICLE VI — CONSIDERATION DUE PLANT SUPPLIER

     6.1 Plant Supplier’s Consideration. Plant Supplier shall receive as full settlement
hereunder each month eighty-four percent (84%) of the Net Proceeds attributable to such Gas for
such month, as allocated to Plant Supplier’s Gas under Article VI hereof, less the Plant Share.
Processor shall be entitled to sixteen percent (16%) of the Net Proceeds attributable to such Gas
for such month (“Processor’s Proceeds”).

     Notwithstanding the foregoing, in no event shall the value of the Processor’s Proceeds be
less than the value of $0.15 per MCF multiplied by the MCF of the Plant Supplier’s Gas at the
Field Delivery Point.

ARTICLE VII — PLANT VOLUME REDUCTION AND BYPASSED GAS

     7.1 General. It is recognized that there will be a reduction in gas volumes, herein
called “Plant Volume Reduction”, between the quantity of gas delivered by Southern for processing
in the Plant and the volume of Residue Gas returned to Southern’s Lines because of (a) extraction
of Raw Make, herein called the “shrinkage portion”, and (b) Plant fuel used, flared gas or other
uses or losses incident to or occasioned by processing.

     7.2 Calculation of Plant Volume Reduction. The Plant Volume Reduction for the entire
Plant shall be accounted for on a monthly basis and shall be calculated as follows:

     7.2.1 Shrinkage Portion. The vapor volume equivalent of each liquid component of the
Raw Make shall be determined by multiplying the liquid volume of such component by the applicable
vapor equivalent factor set forth in the schedule below. The total shrinkage portion of the Plant
Volume Reduction will be equal to the sum of all such conversion computations made for each
component of the Raw Make. Until revised by Plant Owners and Gas Transporters, the vapor equivalent
factors set forth in the schedule below shall be used for all such conversion calculations:

			
	 	 	 
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	 	 	VAPOR EQUIVALENT	 	HEAT EQUIVALENT
	COMPONENTS	 	FACTOR (CF/GAL)	 	FACTOR (MMBTU/GAL)
	Carbon Dioxide
	 	 	57.8528	 	 	 	0.000000	 
	Methane
	 	 	57.8431	 	 	 	0.059729	 
	Ethane
	 	 	36.6672	 	 	 	0.066338	 
	Propane
	 	 	35.5942	 	 	 	0.091563	 
	Iso-Butane
	 	 	29.9662	 	 	 	0.099629	 
	N-Butane
	 	 	31.1047	 	 	 	0.103740	 
	Iso-Pentane
	 	 	26.8137	 	 	 	0.109679	 
	N-Pentane
	 	 	27.0524	 	 	 	0.110869	 
	Hexane
	 	 	23.8466	 	 	 	0.115952	 
	Heptanes Plus*
	 	 	 	 	 	 	 	 

Taken from Gas Processors Association (“GPA”) Publication 2145-09. Vapor Equivalent
factors are in cubic feet per gallon on the Ideal Gas Basis corrected from 14.696 psia to
15.025 psia. Such factors shall be modified from time to time to conform with any amendment
or revision of the above table adopted by the GPA. Heat Equivalent factors are in MMBTU per
Gallon. Such factors shall be modified from time to time to conform with any amendment or
revision of the above table adopted by the GPA.

 

			
	*	 	The Gas/liquid ratio for heptanes plus shall be determined from time to time as may be
necessary to be representative of such components.

The total shrinkage portion of the Plant Volume Reduction will be determined from measurement
by positive displacement liquid meter and monthly composite sampling and analysis of the Raw
Make.

     7.2.2 Determination of Losses. Plant fuel, flared gas and other uses or losses
incident to processing: The volume of gas which is attributable to such uses or losses shall be as
determined by the measurement with meters of each such use occurring in the Plant as may be
necessary to determine accurately the total volume of gas so used, such meters to be installed and
operated as mutually agreed by Plant Owners and Southern.

     7.2.3 Plant Volume Reduction Determination. All Plant Volume Reduction attributable
to any other Plant use, loss or operation shall be determined by a method mutually agreeable to
Plant Owners and Southern. It is understood that Plant Owners and Southern may agree on some other
method of determining Plant Volume Reduction in order to remove any

			
	 	 	 
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inequities which may be found to exist, and it is agreed that any such other method adopted
shall be applicable to this agreement.

     7.3 Sharing of Plant Volume Reduction Among Plant Owners and Plant Suppliers. That
portion of Plant Volume Reduction resulting from Plant fuel shall be the volume measured by orifice
meters. The metered fuel volume shall be allocated to the respective Field Delivery Points of Plant
Owners and Plant Suppliers on the following basis: One-half (1/2) in the same ratio that the sum of
the gallons of propane and heavier Products (calculated separately for each Product) allocated to
each Field Delivery Point bears to the sum of the gallons of propane and heavier Products
(calculated separately for each Product) allocated to all Field Delivery Points, and one-half (1/2)
in the ratio that the volume of gas processed from each such Field Delivery Point bears to the
total volume of gas processed in the Plant. That portion of the Plant Volume Reduction remaining,
after subtracting the metered fuel volume, shall be allocated to the respective Field Delivery
Points of Plant Owners and Plant Suppliers in the same ratio that the sum of the vapor equivalent
of all Products (calculated separately for each Product) allocated to each Field Delivery Point
bears to the sum of the vapor equivalent of all Products (calculated separately for each Product)
allocated to all Field Delivery Points to the Plant.

     7.4 Accounting to Gas Transporter for Plant Volume Reduction. Plant Supplier shall
bear and shall account to Gas Transporter for the full amount of Plant Volume Reduction allocated
to the gas credited as having been processed from the Field Delivery Points for Plant Supplier’s
account monthly on such basis as may be provided in the applicable contract between Plant Supplier
and Southern, or between the Gas Transporter and Southern, it being expressly understood that Plant
Owners have no responsibility for any portion of such Plant Volume Reduction allocated pursuant
hereto to the Field Delivery Points for Plant Supplier’s account. Plant Operator shall, by the end
of the month in which it receives the accounting data required to be furnished by Plant Supplier
under Section 5.5 and such additional accounting data as may be required from Plant Owners, other
Suppliers and Southern, furnish Plant Supplier and other interested parties a statement setting
forth:

			
	 	 	 
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     7.4.1 The total quantity of Plant Volume Reduction; and

     7.4.2 Each Plant Owner’s and Plant Supplier’s proportionate share of the total Plant
Volume Reduction; and

     7.4.3 An allocation of the Plant Volume Reduction applicable to each Field Delivery
Point serving the Plant, and a sub-allocation as to gas which is owned by more than
one Plant Supplier (including for Plant Supplier’s account) to show the amount of
Plant Volume Reduction attributable to each Owner of the gas delivered at such Field
Delivery Point.

The results set forth in such statement each month shall constitute the quantity of Plant Volume
Reduction to be allocated to each Plant Owner and Plant Supplier for the preceding month, and it is
understood that Gas Transporter may rely on such statements in effecting settlement with Plant
Supplier for Plant Supplier’s share of Plant Volume Reduction. Plant Operator shall furnish the
foregoing parties with an allocation statement based on estimated Plant Volume Reduction covering
the first month of Plant operation. Plant Operator’s statement shall also report the volume of gas
bypassed at the Plant during the preceding month and allocation thereof to Plant Owners and/or
Plant Suppliers, including Plant Supplier.

     7.5 Determination of Bypassed Gas. Plant Owners shall install an orifice meter on the
Plant bypass line for the purpose of measuring gas bypassed as herein provided, such meter to be
installed, operated and measurement made thereby in conformity with the requirements agreed upon by
Plant Owners and Southern.

     7.6 Sample Calculation of Plant Volume Reduction Allocation Procedure. The procedure
for calculating and allocating Plant Volume Reduction in accordance with the provisions of this
Article VII is illustrated by Exhibit “B” hereto.

ARTICLE VIII — TERM

     8.1 Term. This agreement shall apply to the gas described in Section 4.1 as of the
Effective Date and shall remain in effect until terminated, effective at the end of any month, by

			
	 	 	 
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either Processor or Plant Supplier on at least sixty (60) days prior written notice to the
other party. This agreement shall also terminate upon the discontinuance of plant operations by
Plant Owners based on their determination, in their sole discretion, that further plant operations
would be unprofitable on at least thirty (30) day’s advanced written notice to the Plant Supplier.

ARTICLE IX — PAYMENT OF ROYALTY AND TAXES

     9.1 Royalty and Other Burdens on Production. Plant Supplier shall be solely
responsible for accounting to or paying to the lessors, royalty owners and the owners, if any, of
oil payments, overriding royalties, or other interests in production, under the lease or leases in
the field or fields covered hereunder for their share, if any, of the Products or the proceeds
derived therefrom attributable to the gas processed for Plant Supplier’s account hereunder.

     9.2 Severance and Other Taxes. Processor shall not be liable for the payment of any
monies due hereunder to the lessors, royalty owners and the owners, if any, of oil payments or
overriding royalties, under the lease or leases in the field or fields covered hereunder. Processor
shall not be liable for any severance, gathering or equivalent Taxes due on the production,
severance and handling of the Gas delivered by Plant Supplier for processing hereunder and the
severance or similar Taxes due on Plant Supplier’s share of products hereunder where the same are
taken in kind. Plant Supplier shall pay or cause to be paid any and all excise, sales, use,
severance, gathering, processing, fuel use, or other similar Taxes or obligations due on the sale,
use, production, severance, processing, transportation or handling of Plant Supplier’s Gas and
condensate delivered to Processor hereunder or on Residue Gas, Products, or Raw Make extracted
therefrom (or the proceeds attributable thereto, as the case may be), except for any Taxes assessed
on the disposition of Processor’s share of such Residue Gas, Products, or Raw Make, if any,
extracted from Plant Supplier’s Gas or condensate.

ARTICLE X — LAWS, REGULATIONS AND FORCE MAJEURE

			
	 	 	 
	L1167	 	 
	American Midstream, LLC
	 	Execution Copy

18

 

     10.1 Agreement Subject to Laws. This agreement shall be subject to all valid and
applicable laws, orders, rules and regulations made by duly constituted governmental authorities.

     10.2 Force Majeure. Performance, other than to make payments due, under this agreement
by the parties hereto, shall be excused in the event such performance is prevented by war, strikes,
fires, floods, tornadoes, lightning, explosions, acts of God or of the public enemy, acts of
governmental authorities, Federal or State regulations, inability or delay in obtaining servitudes,
easements or permits, or material, and other happenings beyond the control of such parties, whether
similar or dissimilar to the matters herein specifically enumerated; provided, however, that prompt
written or telegraphic notice has been given by the party who is claiming to have been excused from
performance by any of such causes to the other party and that performance shall be resumed within a
reasonable time after such cause has been removed; and provided further, that no party hereto shall
be required against its will to adjust any labor dispute.

ARTICLE XI — NOTICES

     All notices, settlement instructions or demands required or provided for herein shall be in
writing and shall be considered as duly delivered when delivered by courier, facsimile, electronic
mail, or mailed by prepaid registered or certified mail, addressed to the party to whom such notice
is given as follows:

	 	 	 

	PLANT SUPPLIER:

	 	Notices:
	 
	 	 
	If by mail, facsimile or courier:

	 	American Midstream, LLC
	 

	 	Attn: Mary Ann Gonzales
	 

	 	8300 FM 1960 West 
	 

	 	Houston TX 77070
	 

	 	 Phone: (281) 955-4815 
	 

	 	Facsimile: (281) 955-4855
	If by electronic mail:

	 	Email: mgonzales@americanmidstream.com

			
	 	 	 
	L1167	 	 
	American Midstream, LLC
	 	Execution Copy

19

 

	 	 	 

	PROCESSOR:

	 	Notices:
	 
	 	 
	If by mail:

	 	Enterprise Gas Processing, LLC
	 

	 	Attn: GOM Gas Processing Contract Administration
	 

	 	P.O. Box 4324
	 

	 	Houston, Texas 77210-4324
	 

	 	Phone: (713) 381-4081
	 

	 	Facsimile: (713) 381-4365
	 
	 	 
	If by courier:

	 	Enterprise Gas Processing, LLC
	 

	 	Attn: GOM Gas Processing Contract Administration
	 

	 	1100 Louisiana, Suite 1500
	 

	 	Houston, Texas 77002
	 

	 	Phone: (713) 381-4081
	 
	 	 
	If by electronic mail:

	 	GOMgasprocessing@eprod.com

or to such other address as either party shall designate by like written notice to the other party.
Routine communications, including statements, computations and allocations, may be transmitted by
ordinary mail or electronic mail.

ARTICLE XII — INDEMNIFICATION

     Processor and Plant Supplier shall indemnify, defend and hold the other harmless from claims,
demands and causes of action of every type and character arising out of the performance of this
agreement which are asserted against the indemnitee by any person (including, without limitation,
Processor’s and Plant Supplier’s employees) for personal injury, death, loss of or damage to
property where such injury, death or loss of or damage to property is due to the sole negligence or
sole willful misconduct of the indemnitor. Where personal injury, death, or loss of or damage to
property is the result of joint negligence or willful misconduct of Processor and Plant Supplier,
the indemnitor’s duty of indemnification shall be in the same proportion that the indemnitor’s
negligent acts or omissions or willful misconduct contributed thereto. If Processor or Plant
Supplier is strictly liable under law, the indemnitor’s duty of indemnification shall be in the
same proportion that the indemnitor’s negligent acts or omissions contributed to the personal
injury, illness, death, or losses of or damage to property for which the indemnitor is strictly
liable.

			
	 	 	 
	L1167	 	 
	American Midstream, LLC
	 	Execution Copy

20

 

ARTICLE XIII — MISCELLANEOUS

     13.1 Access to Plant Supplier’s Premises. Processor shall have the right of access
insofar as Plant Supplier has the right to grant such access to the Field Delivery Point(s) for
Plant Supplier’s accounts for all purposes necessary for the fulfillment of this agreement.

     13.2 Separate Agreement. If the gas which is subject to processing hereunder is
delivered from more than one Field Delivery Point, this agreement shall be considered a separate
agreement as to each such Field Delivery Point and a separate accounting shall be made hereunder
for the gas received from each such Point.

     13.3 Inspection of Records. Each party hereto shall have the right at all reasonable
times during business hours to examine the books, records, charts, meters, measuring equipment and
other pertinent matter or data of the other party relating to this agreement and to witness the
tests of the other party to the extent necessary to verify the accuracy of any statement, charge,
computation or demand under or pursuant to any of the provisions hereof. If any such examination
shall reveal, or if either party shall otherwise discover, any error or inaccuracy in its own or
the other party’s statements, payments, calculations or determinations, then proper adjustment and
correction thereof shall be made as promptly as practicable thereafter; provided that, no
adjustment of any statement, billing or payment shall be made after the lapse of two (2) years from
the rendition thereof.

     13.4 Headings and Subheadings. Except when comprising a part of a sentence, the
headings and subheadings used in this instrument are provided for reference purposes only and shall
not be construed to interpret or amend any part of the text hereof.

     13.5 Successors and Assigns Bound. This agreement shall extend to and be binding upon
the parties hereto, their respective successors and assigns, and shall follow and run with the
title to the leases in the field or fields covered hereby, and the rights of either party may be
assigned or conveyed in whole or in part, but all such assignments and conveyances shall be
subject to this agreement. No transfer or succession to the interest of any party herein shall
affect or bind the non-transferring party until the non-transferring party shall have been
furnished at its address given

			
	 	 	 
	L1167	 	 
	American Midstream, LLC
	 	Execution Copy

21

 

above with the original recorded instrument or a certified copy of the recorded instrument
under which the transfer or succession takes place.

     13.6 Conflicts. To the extent of any conflict between any portion of the written text
of this Agreement or any Exhibit and any of the example(s) contained in this Agreement or any
Exhibit hereto, the example(s) shall control.

     13.7 Media or Press Releases. No party shall issue a media or press release regarding
the matters which are the subject of this Agreement unless such party has obtained the prior
written consent of the other parties, except where such release is deemed in good faith by the
releasing party to be required by applicable laws or applicable rules or regulations of any
governmental body or stock exchange. However, any party that fails to object to a media or press
release within seventy-two (72) hours following proper notice of the proposed media or press
release will be deemed to have consented to such media or press release. The parties shall use
reasonable efforts to unanimously agree upon the timing and content of releases to the news media
concerning operations covered by this Agreement. However, in the event the parties cannot
unanimously agree upon either the timing and/or content of the news release within seventy-two (72)
hours of receipt of such proposed news release, then any party shall be allowed to issue its own
release without the approval of the other parties.

[Signatures are on the next page.]

			
	 	 	 
	L1167	 	 
	American Midstream, LLC
	 	Execution Copy

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     IN WITNESS WHEREOF, this Agreement is executed by the parties hereto on the date first
above written.

	 	 	 	 	 	 	 

	 	 	PLANT SUPPLIER:	 	 
	 
	 	 	 	 	 	 
	 	 	AMERICAN MIDSTREAM, LLC	 	 
	 
	 	 	 	 	 	 
	 

	 	By:	 	/s/ Brian Bierbach	 	 
	 

	 	Name:
	 	 

Brian Bierbach	 	 
	 

	 	Title:
	 	 

President	 	 
	 
	 	 	 	 
	 	 
	 	 	PROCESSOR:	 	 
	 
	 	 	 	 	 	 
	 	 	ENTERPRISE GAS PROCESSING, LLC	 	 
	 
	 	 	 	 	 	 
	 

	 	By:	 	/s/ William S. Goloway 	 	 
	 

	 	 	 	 

William S. Goloway
	 	 
	 

	 	 	 	Regional Director	 	 

			
	 	 	 
	L1167	 	 
	American Midstream, LLC
	 	Execution Copy

1

 

EXHIBIT “A”

TO GAS PROCESSING CONTRACT

TOCA GAS PROCESSING PLANT

ST. BERNARD PARISH, LOUISIANA

EXAMPLE CALCULATION

PROCUT ALLOCATION PROCEDURE

	I.	 	CALCULATION OF TOTAL PLANT PRODUCTS

SUMMARY OF RAW MAKE PRODUCTION

	 	 	 	 	 
	COMPONENT	 	GALLONS	 
	CO2
	 	 	200,000	 
	 
	 	 	 	 
	C1
	 	 	200,000	 
	C2
	 	 	9,000,000	 
	C3
	 	 	5,000,000	 
	IC4
	 	 	1,400,000	 
	NC4
	 	 	1,700,000	 
	IC5
	 	 	800,000	 
	NC5
	 	 	600,000	 
	C6
	 	 	850,000	 
	C7+
	 	 	900,000	 
	 
	 	 	 
	Subtotal          
	 	 	20,650,000	 
	Scrubber          
	 	 	100,000	 
	 
	 	 	 
	Total          
	 	 	20,750,000	 

PLANT PRODUCTS

	 	 	 	 	 
	PRODUCT	 	GALLONS	 
	Ethane
	 	 	9,086,913	 
	 
	 	 	 	 
	Propane
	 	 	5,000,000	 
	Iso-Butane
	 	 	1,400,000	 
	Normal Butane
	 	 	1,700,000	 
	Natural Gasoline
	 	 	3,150,000	 
	Scrubber
	 	 	100,000	 
	 
	 	 	 
	 
	 	 	 	 
	Total          
	 	 	20,436,913	 

The ethane product contains:

	(1)	 	The total ethane component
	 
	(3)	 	All methane up to a maximum of 1.5 mol% of the total ethane product            (0.009657 x C2 Gals)

	II.	 	ALLOCATION OF GASLINE TO FIELD DELIVERY POINTS

	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 
	 	 	 	 	 	 	 	 	 	 	GALLONS	 	 	 	 	 	 
	FIELD DELIVERY	 	GAS CREDITED AS	 	FIELD C5+	 	THEORETICALLY	 	 	 	 	 	ALLOCATED
	POINT	 	PROCESSED IN MCF	 	GPM	 	AVAILABLE	 	FRACTION DUE	 	GALLONS
	 
	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 
	A
	 	 	4,000,000	 	 	 	0.15	 	 	 	600,000	 	 	 	0.181	 	 	 	569,277	 
	B
	 	 	10,000,000	 	 	 	0.20	 	 	 	2,000,000	 	 	 	0.602	 	 	 	1,897,590	 
	C
	 	 	2,400,000	 	 	 	0.30	 	 	 	720,000	 	 	 	0.217	 	 	 	683,133	 
	 
	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 
	 
	 	 	16,400,000	 	 	 	 	 	 	 	3,320,000	 	 	 	 	 	 	 	3,150,000	 

The other Products are allocated in the same manner except that other Producers may receive no
ethane.

Page 1

 

EXHIBIT “B”

PLANT THERMAL REDUCTION

TOCA GAS PROCESSING PLANT

ST. BERNARD PARISH, LOUISIANA

EXAMPLE CALCULATION

	I.	 	TOTAL PLANT THERMAL REDUCTION (SEE EXHBITI “A”)

	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 
	 	 	 	 	 	 	VAPOR/HEAT EQUIVALENT	 	TOTAL	 	 
	SUMMARY OF RAW MAKE PRODUCTION	 	FACTORS	 	SHRINKAGE	 	PLANT FUEL
	COMPONENT	 	GALLONS	 	CF/GAL	 	MMBTU/GAL	 	MCF	 	MMBTU	 	MMBTU	 	MCF
	CO2
	 	 	200,000	 	 	 	57.8528	 	 	 	0.000000	 	 	 	11,571	 	 	 	—	 	 	 	 	 	 	 	 	 
	C1
	 	 	200,000	 	 	 	57.8431	 	 	 	0.059729	 	 	 	11,569	 	 	 	11,946	 	 	 	 	 	 	 	 	 
	C2
	 	 	9,000,000	 	 	 	36.6672	 	 	 	0.066338	 	 	 	330,105	 	 	 	597,045	 	 	 	 	 	 	 	 	 
	C3
	 	 	5,000,000	 	 	 	35.5942	 	 	 	0.091563	 	 	 	177,971	 	 	 	457,813	 	 	 	 	 	 	 	 	 
	IC4
	 	 	1,400,000	 	 	 	29.9662	 	 	 	0.099629	 	 	 	41,953	 	 	 	139,480	 	 	 	 	 	 	 	 	 
	NC4
	 	 	1,700,000	 	 	 	31.1047	 	 	 	0.103740	 	 	 	52,878	 	 	 	176,359	 	 	 	 	 	 	 	 	 
	IC5
	 	 	800,000	 	 	 	26.8137	 	 	 	0.109679	 	 	 	21,451	 	 	 	87,743	 	 	 	 	 	 	 	 	 
	NC5
	 	 	600,000	 	 	 	27.0524	 	 	 	0.110869	 	 	 	16,231	 	 	 	66,521	 	 	 	 	 	 	 	 	 
	C6
	 	 	850,000	 	 	 	23.8466	 	 	 	0.115952	 	 	 	20,270	 	 	 	98,559	 	 	 	 	 	 	 	 	 
	C7+
	 	 	900,000	 	 	 	 	 	 	 	 	 	 	 	21,354	 	 	 	121,977	 	 	 	 	 	 	 	 	 
	Scrubber
	 	 	100,000	 	 	 	 	 	 	 	 	 	 	 	2,372	 	 	 	14,906	 	 	 	 	 	 	 	 	 
	 
	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 
	 
	 	 	20,750,000	 	 	 	 	 	 	 	 	 	 	 	707,624	 	 	 	1,769,349	 	 	 	280,000	 	 	 	293,000	 
	 
	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	1.046	 

	II.	 	DETERMINATION OF HEAT FACTORS FOR ETHANE AND NATURAL GASOLINE

	 	 	 	 	 	 	 

	A.

	 	Ethane Product Heat Factor
	 	=
	 	Total MMBTU for C1 & C2

Total MCF for CO2, C1 & C2
	 
	 	 	 	 	 	 
	 

	 	 	 	=
	 	(   11,946 + 597,045   )

(11,571 + 11,569 + 330,105)
	 
	 	 	 	 	 	 
	 

	 	 	 	=
	 	1.7245 MMBTU/MCF
	 
	 	 	 	 	 	 
	B.

	 	Gasoline Product Heat Factor

     (scrubber heat factor calculated

     in similar manner)
	 	=
	 	Total MMBTU for IC5, NC5, C6 & C7+

Total MCF for IC5, NC5, C6 & C7+
	 

	 	 	 	=
	 	(   87,743 + 66,521 + 98,559 + 121,977   )

(   21,451 + 16,231 + 20,270 + 21,354   )
	 
	 	 	 	 	 	 
	 

	 	 	 	=
	 	4.7260 MMBTU/MCF

Page 2

 

EXHIBIT “B” (continued)

	III.	 	ALLOCATION OF PLANT THERMAL REDUCTION OTO DELIVERY POINT “A”

	 	A.	 	SHRINKAGE PORTION

	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 
	 	 	 	 	 	 	VAPOR	 	HEAT	 	TOTAL
	 	 	ALLOCATED	 	FACTORS	 	FACTORS	 	SHRINKAGE
	PRODUCT	 	GALLONS	 	MCF/GAL	 	MMBTU/MCF	 	MMBTU
	Ethane
	 	 	1,000,000	 	 	 	0.03886	 	 	 	1.7245	 	 	 	67,018	 
	Propane
	 	 	500,000	 	 	 	0.03559	 	 	 	2.5724	 	 	 	45,781	 
	Iso-Butane
	 	 	100,000	 	 	 	0.02997	 	 	 	3.3247	 	 	 	9,963	 
	Normal Butane
	 	 	100,000	 	 	 	0.03111	 	 	 	3.3352	 	 	 	10,374	 
	Gasoline
	 	 	403,846	 	 	 	0.02518	 	 	 	4.7260	 	 	 	48,051	 
	Scrubber
	 	 	12,821	 	 	 	0.02372	 	 	 	5.0195	 	 	 	1,527	 
	 
	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 
	Total
	 	 	2,116,667	 	 	 	 	 	 	 	 	 	 	 	182,714	 

	 	 	 	 	 	 	 	 	 

	   B.	 	FUEL PORTION	 	 	 	 
	 
	 	 	 	 	 	 	 	 
	 
	 	1.	 	Half allocated on gas volume	 	=	 	50% x 4,000,000 / 16,400,000 x 293,000 MMBTU
	 
	 	 	 	 	 	=	 	35,732 MMBTU
	 
	 	 	 	 	 	 	 	 
	 
	 	2.	 	Half allocated on C3+ Products	 	=	 	50% x 1,103,846 / 11,250,000 x 293,000 MMBTU
	 
	 	 	 	 	 	=	 	14,475 MMBTU
	 
	 	 	 	 	 	 	 	 
	 
	 	3.	 	Total Fuel Allocation	 	=	 	50,106 MMBTU
	 
	 	 	 	 	 	 	 	 
	   C.	 	FLARE & OTHER LOSSES PORTION	 	 	 	2,000 MMBTU
	 
	 	 	 	 	 	 	 	 
	 
	 	 	 	Allocated based on Shrinkage	 	=	 	182,714 / 1,769,349 x 2,000
	 
	 	 	 	 	 	=	 	207 MMBTU

Page 3

 

EXHIBIT “C”

TO

GAS PROCESSING AGREEMENT

TOCA GAS PROCESSING PLANT

ST. BERNARD PARISH, LOUISIANA

FRACTIONATION FEE

Beginning on the effective date of this Agreement, and on the first day of each month thereafter
with respect to fuel gas, the Fractionation Fee shall be calculated based on the following formula
(expressed in cents/Gallon):

	 	 	 	 	 	 	 

	(W)(1.20)

	 	+
	 	(2.40) =
	 	Fractionation Fee
	 
	 	 	 	 	 	 
	$4.00/MMBTU

	 	 	 	 	 	¢/Gallon

     With respect to the formula above, the following definition shall apply:

W = The settlement price in dollars per MMBtu, for the Henry Hub index (“Index”), as published in
Inside F.E.R.C.’s Gas Market Report (“IFERC”), in effect for the month in which the Gas is being
processed (e.g. IFERC price published on/near last day of February for March gas flows).

Notwithstanding anything to the contrary herein, in no event shall the adjustments permitted by the
formula appearing above in this Agreement reduce the Fractionation
Fee below 3.60 cents ($0.0360)
per gallon (the “Fractionation Fee Floor”). In the event that the computation of the Fractionation
Fee, as herein provided, results in an amount that is less than the
3.60 cents ($0.0360) per
gallon, then the Parties acknowledge and agree that the Fractionation
Fee shall be 3.60 cents
($0.0360) per gallon. In the event that anything in this Agreement conflicts or otherwise restricts
the application of the Fractionation Fee Floor, the Fractionation Fee Floor shall fully apply and
control.

			
	 	 	 
	L1167	 	 
	American Midstream, LLC
	 	Execution Copy

2

 

EXHIBIT “D”

GAS PROCESSING AGREEMENT

TOCA GAS PROCESSING PLANT

ST. BERNARD PARISH, LOUISIANA

PRODUCT INDEX BASES

	 	 	 
	Product	 	Pricing Basis
	Ethane

	 	OPIS monthly average (of daily high and low) price for
Napoleonville ethane, less $0.005/gallon.
	 
	 	 
	Propane

	 	OPIS monthly average (of daily high and low) price for
Napoleonville propane, less $0.0125/gallon.
	 
	 	 
	Isobutane

	 	OPIS monthly average (of daily high and low) price for
Napoleonville isobutane, less $0.005/gallon.
	 
	 	 
	Normal Butane

	 	OPIS monthly average (of daily high and low) price for
Napoleonville normal butane, less $0.0125/gallon.
	 
	 	 
	Natural Gasoline

	 	OPIS monthly average (of daily high and low) price for
Napoleonville natural gasoline, less $0.005/gallon.

NOTE: The above basis pricing reflects the Toca gas plant’s existing agreement for sale by the
plant of natural gas liquids fob the Norco Fractionator Plant. The pricing basis herein may
change from time-to-time, and upon notification of such change to Plant Supplier, the new
pricing basis will become effective for the month following the month of such notification.

			
	 	 	 
	L1167	 	 
	American Midstream, LLC
	 	Execution Copy

3

 

EXHIBIT “E”

TO

GAS PROCESSING AGREEMENT

TOCA GAS PROCESSING PLANT

ST. BERNARD PARISH, LOUISIANA

PLANT SUPPLIER’S FIELDS FOR PROCESSING

FIELDS FOR WHICH PLANT SUPPLIER HOLDS PROCESSING RIGHTS TO GAS PRODUCED

THEREFROM AND WHICH IS TO BE PROCESSED HEREUNDER:

	 	 	 

	Delivery Point
	 	Southern Meter Number
	 
	 	 
	Creole Receiving Station
	 	039500

			
	 	 	 
	L1167	 	 
	American Midstream, LLC
	 	Execution Copy

4

 

EXHIBIT “F”

TO

GAS PROCESSING AGREEMENT

TOCA GAS PROCESSING PLANT

ST. BERNARD PARISH, LOUISIANA

SETTLEMENT INSTRUCTIONS

American Midstream, LLC (“Plant Supplier”)

Payments to Plant Supplier (wire):

Comerica Bank

ABA: # 111000753

Account No.: 1881319493

For credit to: American Midstream, LLC

Federal Tax ID # 27-0855925

Plant Supplier’s Invoices/Statement Address:

American Midstream, LLC

Attn: Peter McNamara

8300 FM 1960 West

Houston TX 77070

Phone: (281) 955-4709

Fax: (281) 955-4855

Email Address: Peter McNamara PMcnamara@americanmidstream.com

COPY TO:

American Midstream, LLC Attn: Kristy

Karm and Denise Tubb 

1614 15th Street, Suite 300

Denver CO 80202 

Fax: (720) 457-6040

Email Addresses: Kristy Karm       KKarm@americanmidstream.com

               
             Denise Tubb       DTubb@americanmidstream.com

			
	 	 	 
	L1167	 	 
	American Midstream, LLC
	 	Execution Copy

5

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