10-Q

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

WASHINGTON, D.C. 20549

FORM 10-Q

x	QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934
	For the quarterly period ended June 30, 2016

OR

¨	TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934
	For the transition period from  to .

(Exact name of registrant as specified in its charter)	Commission file number	State or other jurisdiction of incorporation or organization	(I.R.S. Employer Identification No.)
Crestwood Equity Partners LP	001-34664	Delaware	43-1918951
Crestwood Midstream Partners LP	001-35377	Delaware	20-1647837

700 Louisiana Street, Suite 2550 Houston, Texas	77002
(Address of principal executive offices)	(Zip code)

(832) 519-2200

(Registrant’s telephone number, including area code)

Indicate by check mark whether the registrant (1) has filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrant was required to file such reports), and (2) has been subject to such filing requirements for the past 90 days.

Crestwood Equity Partners LP	Yes  x  No  o
Crestwood Midstream Partners LP	Yes  x  No  o

(Explanatory Note: Crestwood Midstream Partners LP is currently a voluntary filer and is not subject to the filing requirements of the Securities Exchange Act of 1934. Although not subject to these filing requirements, Crestwood Midstream Partners LP has filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months.)

Indicate by check mark whether the registrant has submitted electronically and posted on its corporate Web site, if any, every Interactive Data File required to be submitted and posted pursuant to Rule 405 of Regulation S-T (§232.405 of this chapter) during the preceding 12 months (or for such shorter period that the registrant was required to submit and post such files).

Crestwood Equity Partners LP	Yes  x  No  o
Crestwood Midstream Partners LP	Yes  x  No  o

Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, or a smaller reporting company. See the definitions of “large accelerated filer,” “accelerated filer” and “smaller reporting company” in Rule 12b-2 of the Exchange Act.

Crestwood Equity Partners LP	Large accelerated filer o	Accelerated filer x	Non-accelerated filer o	Smaller reporting company o
Crestwood Midstream Partners LP	Large accelerated filer o	Accelerated filer o	Non-accelerated filer x	Smaller reporting company o

Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act).

Crestwood Equity Partners LP	Yes  o    No  x
Crestwood Midstream Partners LP	Yes  o    No  x

Indicate the number of shares outstanding of each of the issuer's classes of common stock, as of the latest practicable date (July 29, 2016)

Crestwood Equity Partners LP	69,054,059
Crestwood Midstream Partners LP	None

Crestwood Midstream Partners LP, as a wholly-owned subsidiary of a reporting company, meets the conditions set forth in General Instruction H(1)(a) and (b) of Form 10-Q and is therefore filing this report with the reduced disclosure format as permitted by such instruction.

CRESTWOOD EQUITY PARTNERS LP

CRESTWOOD MIDSTREAM PARTNERS LP

INDEX TO FORM 10-Q

	Page
Part I – Financial Information
Item 1. Financial Statements (Unaudited):
Crestwood Equity Partners LP
Consolidated Balance Sheets	4
Consolidated Statements of Operations	5
Consolidated Statements of Comprehensive Income	7
Consolidated Statement of Partners’ Capital	8
Consolidated Statements of Cash Flows	9
Crestwood Midstream Partners LP
Consolidated Balance Sheets	10
Consolidated Statements of Operations	11
Consolidated Statement of Partners’ Capital	13
Consolidated Statements of Cash Flows	14
Notes to Consolidated Financial Statements	15
Item 2. Management’s Discussion and Analysis of Financial Condition and Results of Operations	45
Item 3. Quantitative and Qualitative Disclosures About Market Risk	60
Item 4. Controls and Procedures	60
Part II – Other Information
Item 1. Legal Proceedings	61
Item 1A. Risk Factors	61
Item 2. Unregistered Sales of Equity Securities and Use of Proceeds	61
Item 3. Defaults Upon Senior Securities	61
Item 4. Mine Safety Disclosures	61
Item 5. Other Information	61
Item 6. Exhibits	62
Signature	64

3

PART I - FINANCIAL INFORMATION

Item 1. Financial Statements

CRESTWOOD EQUITY PARTNERS LP CONSOLIDATED BALANCE SHEETS (in millions, except unit information)
	June 30, 2016		December 31, 2015
	(unaudited)
Assets
Current assets:
Cash	$	0.9	$	0.5
Accounts receivable	247.5		236.5
Inventory	43.5		44.5
Assets from price risk management activities	9.5		32.6
Assets held for sale	55.0		—
Prepaid expenses and other current assets	10.9		21.7
Total current assets	367.3		335.8
Property, plant and equipment	2,538.9		3,747.7
Less: accumulated depreciation and depletion	390.9		436.9
Property, plant and equipment, net	2,148.0		3,310.8
Intangible assets	946.8		975.8
Less: accumulated amortization	225.0		206.6
Intangible assets, net	721.8		769.2
Goodwill	249.5		1,085.5
Investment in unconsolidated affiliates (Note 4)	1,099.1		254.3
Other assets	7.7		7.2
Total assets	$	4,593.4	$	5,762.8
Liabilities and partners’ capital
Current liabilities:
Accounts payable	$	164.5	$	144.1
Accrued expenses and other liabilities (Note 3)	101.2		105.6
Liabilities from price risk management activities	10.9		7.4
Current portion of long-term debt (Note 7)	0.9		1.1
Total current liabilities	277.5		258.2
Long-term debt, less current portion (Note 7)	1,581.6		2,501.8
Other long-term liabilities	45.1		47.5
Deferred income taxes	7.8		8.4
Commitments and contingencies (Note 10)
Partners’ capital (Note 9):
Crestwood Equity Partners LP partners’ capital (69,487,799 and 68,555,305 common and subordinated units issued and outstanding at June 30, 2016 and December 31, 2015)	1,948.1		2,227.6
Preferred units (63,559,359 and 60,718,245 units issued and outstanding at June 30, 2016 and December 31, 2015)	545.5		535.8
Total Crestwood Equity Partners LP partners’ capital	2,493.6		2,763.4
Interest of non-controlling partners in subsidiaries	187.8		183.5
Total partners’ capital	2,681.4		2,946.9
Total liabilities and partners’ capital	$	4,593.4	$	5,762.8

See accompanying notes.

4

CRESTWOOD EQUITY PARTNERS LP CONSOLIDATED STATEMENTS OF OPERATIONS (in millions, except unit and per unit data) (unaudited)
	Three Months Ended						Six Months Ended
	June 30,						June 30,
	2016			2015			2016			2015
Revenues:
Product revenues:
Gathering and processing	$	199.1		$	263.3		$	361.6		$	524.2
Marketing, supply and logistics	257.4			196.5			463.9			473.7
	456.5			459.8			825.5			997.9
Services revenues:
Gathering and processing	69.7			82.4			145.4			170.8
Storage and transportation	53.8			68.5			113.2			136.1
Marketing, supply and logistics	21.2			29.7			52.4			66.1
Related party (Note 11)	0.7			1.1			1.4			2.1
	145.4			181.7			312.4			375.1
Total revenues	601.9			641.5			1,137.9			1,373.0
Costs of product/services sold (exclusive of items shown separately below):
Product costs:
Gathering and processing	221.9			285.3			397.3			543.5
Marketing, supply and logistics	210.0			147.1			376.0			389.3
Related party (Note 11)	4.4			7.7			8.7			16.0
	436.3			440.1			782.0			948.8
Service costs:
Gathering and processing	—			0.1			0.1			0.3
Storage and transportation	1.9			5.3			4.8			10.6
Marketing, supply and logistics	11.8			14.0			26.5			29.5
	13.7			19.4			31.4			40.4
Total costs of products/services sold	450.0			459.5			813.4			989.2
Expenses:
Operations and maintenance	45.0			43.9			86.8			94.5
General and administrative	28.9			30.6			51.9			58.1
Depreciation, amortization and accretion	64.4			74.8			126.7			149.0
	138.3			149.3			265.4			301.6
Other operating expenses:
Loss on long-lived assets, net	(32.7		)	(0.6		)	(32.7		)	(1.6		)
Goodwill impairment	—			(281.0		)	(109.7		)	(281.0		)
Operating loss	(19.1		)	(248.9		)	(83.3		)	(200.4		)

5

CRESTWOOD EQUITY PARTNERS LP CONSOLIDATED STATEMENTS OF OPERATIONS (continued) (in millions, except unit and per unit data) (unaudited)
	Three Months Ended						Six Months Ended
	June 30,						June 30,
	2016			2015			2016			2015
Earnings from unconsolidated affiliates, net	6.2			5.0			12.7			8.4
Interest and debt expense, net	(34.3		)	(35.4		)	(70.4		)	(69.0		)
Gain (loss) on modification/extinguishment of debt	10.0			(17.1		)	10.0			(17.1		)
Other income, net	0.1			0.1			0.2			0.3
Loss before income taxes	(37.1		)	(296.3		)	(130.8		)	(277.8		)
Provision (benefit) for income taxes	—			(0.3		)	—			0.1
Net loss	(37.1		)	(296.0		)	(130.8		)	(277.9		)
Net income (loss) attributable to non-controlling partners	6.0			(256.0		)	11.9			(246.2		)
Net loss attributable to Crestwood Equity Partners LP	(43.1		)	(40.0		)	(142.7		)	(31.7		)
Net income attributable to preferred units	8.1			—			9.7			—
Net loss attributable to partners	$	(51.2	)	$	(40.0	)	$	(152.4	)	$	(31.7	)
Subordinated unitholders' interest in net loss	$	—		$	(0.9	)	$	—		$	(0.7	)
Common unitholders' interest in net loss	$	(51.2	)	$	(39.1	)	$	(152.4	)	$	(31.0	)
Net loss per limited partner unit:
Basic	$	(0.74	)	$	(2.14	)	$	(2.21	)	$	(1.69	)
Diluted	$	(0.74	)	$	(2.14	)	$	(2.21	)	$	(1.70	)
Weighted-average limited partners’ units outstanding (in thousands):
Basic	69,044			18,284			68,978			18,282
Dilutive units	—			439			—			439
Diluted	69,044			18,723			68,978			18,721

See accompanying notes.

6

CRESTWOOD EQUITY PARTNERS LP CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (in millions) (unaudited)
	Three Months Ended						Six Months Ended
	June 30,						June 30,
	2016			2015			2016			2015
Net loss	$	(37.1	)	$	(296.0	)	$	(130.8	)	$	(277.9	)
Change in fair value of Suburban Propane Partners, L.P. units	0.5			(0.4		)	1.3			(0.4		)
Comprehensive loss	(36.6		)	(296.4		)	(129.5		)	(278.3		)
Comprehensive income (loss) attributable to non-controlling interest	6.0			(256.0		)	11.9			(246.2		)
Comprehensive loss attributable to Crestwood Equity Partners LP	$	(42.6	)	$	(40.4	)	$	(141.4	)	$	(32.1	)

See accompanying notes.

7

CRESTWOOD EQUITY PARTNERS LP CONSOLIDATED STATEMENT OF PARTNERS’ CAPITAL (in millions) (unaudited)
	Preferred			Partners'
	Units	Capital		Common Units	Subordinated Units	Capital			Non-Controlling Partners			Total Partners’ Capital
Balance at December 31, 2015	60.7	$	535.8	68.2	0.4	$	2,227.6		$	183.5		$	2,946.9
Distributions to partners	2.8	—		—	—	(137.0		)	(7.6		)	(144.6		)
Unit-based compensation charges	—	—		0.9	—	9.3			—			9.3
Taxes paid for unit-based compensation vesting	—	—		—	—	(0.6		)	—			(0.6		)
Change in fair value of Suburban units	—	—		—	—	1.3			—			1.3
Other	—	—		—	—	(0.1		)	—			(0.1		)
Net income (loss)	—	9.7		—	—	(152.4		)	11.9			(130.8		)
Balance at June 30, 2016	63.5	$	545.5	69.1	0.4	$	1,948.1		$	187.8		$	2,681.4

See accompanying notes.

8

CRESTWOOD EQUITY PARTNERS LP CONSOLIDATED STATEMENTS OF CASH FLOWS (in millions) (unaudited)
	Six Months Ended
	June 30,
	2016			2015
Operating activities
Net loss	$	(130.8	)	$	(277.9	)
Adjustments to reconcile net loss to net cash provided by operating activities:
Depreciation, amortization and accretion	126.7			149.0
Amortization of debt-related deferred costs, discounts and premiums	3.4			4.4
Market adjustment on interest rate swaps	—			(0.5		)
Unit-based compensation charges	9.3			11.7
Loss on long-lived assets, net	32.7			1.6
Goodwill impairment	109.7			281.0
(Gain) loss on modification/extinguishment of debt	(10.0		)	17.1
Earnings from unconsolidated affiliates, net, adjusted for cash distributions received	(0.8		)	(2.1		)
Deferred income taxes	(0.6		)	(1.6		)
Other	0.1			0.4
Changes in operating assets and liabilities	53.3			28.0
Net cash provided by operating activities	193.0			211.1
Investing activities
Purchases of property, plant and equipment	(76.2		)	(83.5		)
Investment in unconsolidated affiliates	(5.5		)	(28.0		)
Capital distributions from unconsolidated affiliates	5.5			1.0
Net proceeds from sale of assets	942.0			2.1
Net cash provided by (used in) investing activities	865.8			(108.4		)
Financing activities
Proceeds from the issuance of long-term debt	1,078.8			2,154.6
Principal payments on long-term debt	(1,987.7		)	(2,030.6		)
Payments on capital leases	(0.9		)	(1.2		)
Payments for debt-related deferred costs	(3.3		)	(11.7		)
Financing fees paid for early debt redemption	—			(13.6		)
Distributions to partners	(137.0		)	(51.5		)
Distributions paid to non-controlling partners	(7.6		)	(152.4		)
Taxes paid for unit-based compensation vesting	(0.6		)	(3.7		)
Other	(0.1		)	(0.1		)
Net cash used in financing activities	(1,058.4		)	(110.2		)
Net change in cash	0.4			(7.5		)
Cash at beginning of period	0.5			8.8
Cash at end of period	$	0.9		$	1.3
Supplemental schedule of noncash investing and financing activities
Net change to property, plant and equipment through accounts payable and accrued expenses	$	(11.9	)	$	(11.3	)

See accompanying notes.

9

CRESTWOOD MIDSTREAM PARTNERS LP CONSOLIDATED BALANCE SHEETS (in millions)
	June 30, 2016		December 31, 2015
	(unaudited)
Assets
Current assets:
Cash	$	0.2	$	0.1
Accounts receivable	244.3		236.5
Inventory	43.5		44.5
Assets from price risk management activities	9.5		32.6
Assets held for sale	55.0		—
Prepaid expenses and other current assets	10.3		19.9
Total current assets	362.8		333.6
Property, plant and equipment	2,869.0		4,077.7
Less: accumulated depreciation and depletion	513.1		552.0
Property, plant and equipment, net	2,355.9		3,525.7
Intangible assets	930.3		959.3
Less: accumulated amortization	214.6		197.9
Intangible assets, net	715.7		761.4
Goodwill	249.5		1,085.5
Investment in unconsolidated affiliates (Note 4)	1,099.1		254.3
Other assets	2.9		3.1
Total assets	$	4,785.9	$	5,963.6
Liabilities and partners’ capital
Current liabilities:
Accounts payable	$	161.8	$	141.4
Accrued expenses and other liabilities (Note 3)	94.5		103.3
Liabilities from price risk management activities	10.9		7.4
Current portion of long-term debt (Note 7)	0.9		0.9
Total current liabilities	268.1		253.0
Long-term debt, less current portion (Note 7)	1,581.6		2,501.8
Other long-term liabilities	40.9		43.3
Deferred income taxes	0.7		0.4
Commitments and contingencies (Note 10)
Partners’ capital (Note 9):
Partners’ capital	2,706.8		2,981.6
Interest of non-controlling partners in subsidiary	187.8		183.5
Total partners’ capital	2,894.6		3,165.1
Total liabilities and partners’ capital	$	4,785.9	$	5,963.6

See accompanying notes.

10

CRESTWOOD MIDSTREAM PARTNERS LP CONSOLIDATED STATEMENTS OF OPERATIONS (in millions) (unaudited)
	Three Months Ended						Six Months Ended
	June 30,						June 30,
	2016			2015(1)			2016			2015(1)
Revenues:
Product revenues:
Gathering and processing	$	199.1		$	263.3		$	361.6		$	524.2
Marketing, supply and logistics	257.4			196.5			463.9			473.7
	456.5			459.8			825.5			997.9
Service revenues:
Gathering and processing	69.7			82.4			145.4			170.8
Storage and transportation	53.8			68.5			113.2			136.1
Marketing, supply and logistics	21.2			29.7			52.4			66.1
Related party (Note 11)	0.7			1.1			1.4			2.1
	145.4			181.7			312.4			375.1
Total revenues	601.9			641.5			1,137.9			1,373.0
Costs of product/services sold (exclusive of items shown separately below):
Product costs:
Gathering and processing	221.9			285.3			397.3			543.5
Marketing, supply and logistics	210.0			147.1			376.0			389.3
Related party (Note 11)	4.4			7.7			8.7			16.0
	436.3			440.1			782.0			948.8
Service costs:
Gathering and processing	—			0.1			0.1			0.3
Storage and transportation	1.9			5.3			4.8			10.6
Marketing, supply and logistics	11.8			14.0			26.5			29.5
	13.7			19.4			31.4			40.4
Total costs of product/services sold	450.0			459.5			813.4			989.2
Expenses:
Operations and maintenance	41.4			43.9			83.1			94.5
General and administrative	28.0			27.3			50.2			52.9
Depreciation, amortization and accretion	67.1			69.5			132.0			138.3
	136.5			140.7			265.3			285.7
Other operating expenses:
Loss on long-lived assets, net	(32.7		)	(0.7		)	(32.7		)	(1.5		)
Goodwill impairment	—			(68.6		)	(109.7		)	(68.6		)
Operating income (loss)	(17.3		)	(28.0		)	(83.2		)	28.0

11

CRESTWOOD MIDSTREAM PARTNERS LP CONSOLIDATED STATEMENTS OF OPERATIONS (continued) (in millions) (unaudited)
	Three Months Ended						Six Months Ended
	June 30,						June 30,
	2016			2015(1)			2016			2015(1)
Earnings from unconsolidated affiliates, net	6.2			5.0			12.7			8.4
Interest and debt expense, net	(34.3		)	(32.6		)	(70.4		)	(62.5		)
Gain (loss) on modification/extinguishment of debt	10.0			(17.1		)	10.0			(17.1		)
Loss before income taxes	(35.4		)	(72.7		)	(130.9		)	(43.2		)
Provision for income taxes	0.2			0.1			—			0.5
Net loss	(35.6		)	(72.8		)	(130.9		)	(43.7		)
Net income attributable to non-controlling partners	6.0			5.7			11.9			11.3
Net loss attributable to Crestwood Midstream Partners LP	(41.6		)	(78.5		)	(142.8		)	(55.0		)
Net income attributable to Class A preferred units	—			7.5			—			16.7
Net loss attributable to partners	$	(41.6	)	$	(86.0	)	$	(142.8	)	$	(71.7	)

⁽¹⁾ Retrospectively adjusted to reflect the operations of Crestwood Operations LLC as discussed in Note 2.

See accompanying notes.

12

CRESTWOOD MIDSTREAM PARTNERS LP CONSOLIDATED STATEMENTS OF PARTNERS’ CAPITAL (in millions) (unaudited)
	Partners			Non-Controlling Partners			Total Partners’ Capital
Balance at December 31, 2015	$	2,981.6		$	183.5		$	3,165.1
Distributions to partners	(140.6		)	(7.6		)	(148.2		)
Unit-based compensation charges	9.3			—			9.3
Taxes paid for unit-based compensation vesting	(0.6		)	—			(0.6		)
Other	(0.1		)	—			(0.1		)
Net income (loss)	(142.8		)	11.9			(130.9		)
Balance at June 30, 2016	$	2,706.8		$	187.8		$	2,894.6

See accompanying notes.

13

CRESTWOOD MIDSTREAM PARTNERS LP CONSOLIDATED STATEMENTS OF CASH FLOWS (in millions) (unaudited)
	Six Months Ended
	June 30,
	2016			2015(1)
Operating activities
Net loss	$	(130.9	)	$	(43.7	)
Adjustments to reconcile net loss to net cash provided by operating activities:
Depreciation, amortization and accretion	132.0			138.3
Amortization of debt-related deferred costs and premiums	3.4			3.9
Unit-based compensation charges	9.3			10.5
Goodwill impairment	109.7			68.6
Loss on long-lived assets	32.7			1.5
(Gain) loss on modification/extinguishment of debt	(10.0		)	17.1
Earnings from unconsolidated affiliates, net, adjusted for cash distributions received	(0.8		)	(2.1		)
Deferred income taxes	0.2			0.3
Other	0.1			0.2
Changes in operating assets and liabilities	50.3			8.9
Net cash provided by operating activities	196.0			203.5
Investing activities
Purchases of property, plant and equipment	(76.2		)	(83.5		)
Investment in unconsolidated affiliates	(5.5		)	(27.8		)
Capital distributions from unconsolidated affiliates	5.5			1.0
Net proceeds from sale of assets	942.0			2.1
Net cash provided by (used in) investing activities	865.8			(108.2		)
Financing activities
Proceeds from the issuance of long-term debt	1,078.8			1,865.1
Principal payments on long-term debt	(1,987.5		)	(1,713.2		)
Payments on capital leases	(0.9		)	(1.2		)
Payments for debt-related deferred costs	(3.3		)	(11.7		)
Financing fees paid for early debt redemption	—			(13.6		)
Distributions to partners	(148.2		)	(225.2		)
Taxes paid for unit-based compensation vesting	(0.6		)	(2.1		)
Other	—			(0.2		)
Net cash used in financing activities	(1,061.7		)	(102.1		)
Net change in cash	0.1			(6.8		)
Cash at beginning of period	0.1			7.6
Cash at end of period	$	0.2		$	0.8
Supplemental schedule of non-cash investing and financing activities
Net change to property, plant and equipment through accounts payable and accrued expenses	$	(11.9	)	$	(11.3	)

⁽¹⁾ Retrospectively adjusted to reflect the operations of Crestwood Operations LLC as discussed in Note 2.

See accompanying notes.

14

CRESTWOOD EQUITY PARTNERS LP

CRESTWOOD MIDSTREAM PARTNERS LP

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(unaudited)

Note 1 – Organization and Business Description

The accompanying notes to the consolidated financial statements apply to Crestwood Equity Partners LP and Crestwood Midstream Partners LP, unless otherwise indicated. References in this report to “we,” “us,” “our,” “ours,” “our company,” the “partnership,” the “Company,” "Crestwood Equity," “CEQP,” and similar terms refer to either Crestwood Equity Partners LP itself or Crestwood Equity Partners and its consolidated subsidiaries, as the context requires. Unless otherwise indicated, references to "Crestwood Midstream" and "CMLP" refer to Crestwood Midstream Partners LP and its consolidated subsidiaries.

The accompanying consolidated financial statements and related notes should be read in conjunction with our 2015 Annual Report on Form 10-K filed with the Securities and Exchange Commission (SEC) on February 29, 2016. The financial information as of June 30, 2016, and for the three and six months endedJune 30, 2016 and 2015, is unaudited. The consolidated balance sheets as of December 31, 2015, were derived from the audited balance sheets filed in our 2015 Annual Report on Form 10-K.

Organization

Crestwood Equity is a publicly-traded (NYSE: CEQP) Delaware limited partnership that develops, acquires, owns or controls, and operates primarily fee-based assets and operations within the energy midstream sector. We provide broad-ranging infrastructure solutions across the value chain to service premier liquids-rich natural gas and crude oil shale plays across the United States. We own and operate a diversified portfolio of crude oil and natural gas gathering, processing, storage and transportation assets and connect fundamental energy supply with energy demand across North America. Crestwood Equity is a holding company and all of its consolidated operating assets are owned by or through its wholly-owned subsidiary, Crestwood Midstream, a Delaware limited partnership.

Description of Business

In conjunction with the Simplification Merger (as defined in Note 2), we modified our segments and our financial statements to reflect three operating and reporting segments: (i) gathering and processing operations; (ii) storage and transportation operations; and (iii) marketing, supply and logistics operations (formerly NGL and crude services operations). Consequently, the results of our Arrow operations are now reflected in our gathering and processing operations for all periods presented and our COLT and Powder River Basin Industrial Complex, LLC (PRBIC) operations are now reflected in our storage and transportation operations for all periods presented. These respective operations were previously included in our NGL and crude services operations. For a further description of our operating and reporting segments, see our 2015 Annual Report on Form 10-K.

Note 2 – Basis of Presentation and Summary of Significant Accounting Policies

Basis of Presentation

Our consolidated financial statements are prepared in accordance with accounting principles generally accepted in the United States of America (GAAP) and include the accounts of all consolidated subsidiaries after the elimination of all intercompany accounts and transactions. In management’s opinion, all necessary adjustments to fairly present our results of operations, financial position and cash flows for the periods presented have been made and all such adjustments are of a normal and recurring nature. Certain information and footnote disclosures normally included in annual consolidated financial statements prepared in accordance with GAAP have been omitted pursuant to the rules and regulations of the SEC.

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In May 2015, CEQP, Crestwood Midstream and certain of their affiliates entered into a definitive agreement under which Crestwood Midstream would merge with a wholly-owned subsidiary of CEQP, with Crestwood Midstream surviving as a wholly-owned subsidiary of CEQP (the Simplification Merger). In conjunction with the closing of the Simplification Merger on September 30, 2015, Crestwood Equity contributed 100% of its interest in Crestwood Operations LLC (Crestwood Operations) to Crestwood Midstream. As a result of this equity transaction, Crestwood Midstream controls the operating and financial decisions of Crestwood Operations. Crestwood Midstream accounted for this transaction as a reorganization of entities under common control and the accounting standards related to such transactions requires Crestwood Midstream to retroactively adjust Crestwood Midstream's historical results to reflect the operations of Crestwood Operations as being acquired on June 19, 2013, the date in which Crestwood Midstream and Crestwood Operations came under common control. Prior to the Simplification Merger, Crestwood Equity consolidated the results of Crestwood Operations in its financial statements and as such, this transaction had no impact on its historical financial statements.

Beginning in the third quarter of 2015, we changed our income statement to classify the revenues associated with the products to which we take title as product revenues in our consolidated statement of operations. As such, we reclassified our historical consolidated statements of operations for the three and six months endedJune 30, 2015 to reflect this change. We classify all other revenues as service revenues in our consolidated statement of operations.

Significant Accounting Policies

There were no material changes in our significant accounting policies from those described in our 2015 Annual Report on Form 10-K. Below is an update of certain of our accounting policies.

Principles of Consolidation

We consolidate entities when we have the ability to control or direct the operating and financial decisions of the entity or when we have a significant interest in the entity that give us the ability to direct the activities that are significant to that entity. The determination to consolidate or apply the equity method of accounting to an entity can also require us to evaluate whether the entity is considered a variable interest entity. This evaluation, along with the determination of our ability to control, direct or exert significant influence over an entity involves the use of judgment. We apply the equity method of accounting where we can exert significant influence over, but do not control or direct the policies, decisions or activities of an entity. We use the cost method of accounting where we are unable to exert significant influence over the entity.

In April 2016, our wholly-owned subsidiary, Crestwood Pipeline and Storage Northeast LLC (Crestwood Northeast) and Con Edison Gas Pipeline and Storage Northeast, LLC (CEGP), a wholly-owned subsidiary of Consolidated Edison, Inc. (Con Edison), entered into a definitive agreement to form a joint venture, Stagecoach Gas Services LLC (Stagecoach Gas), to own and further develop our existing natural gas pipeline and storage business located in southern New York and northern Pennsylvania (the NE S&T assets) and our 37.5 mile intrastate natural gas pipeline located in New York which is owned by Crestwood Pipeline East LLC (Pipeline East). On June 3, 2016, we contributed to Stagecoach Gas the entities owning the NE S&T assets, CEGP contributed $945 million to Stagecoach Gas in exchange for a 50% equity interest in Stagecoach Gas, and Stagecoach Gas distributed to Crestwood Northeast the net cash proceeds received from CEGP. Our NE S&T assets were previously included in our storage and transportation segment.

Effective June 3, 2016, we deconsolidated the NE S&T assets as a result of the contribution of these assets to Stagecoach Gas as described above and began accounting for our 50% equity interest in Stagecoach Gas under the equity method of accounting and recorded our Pipeline East assets as assets held for sale as of June 30, 2016. See Notes 3 and 4 for a further discussion of our investment in Stagecoach Gas and our assets held for sale. The deconsolidation of our NE S&T assets resulted in a decrease of $1,094.6 million in property, plant and equipment, net, $8.5 million of intangible assets, net and $10.9 million of other assets and liabilities, net as of June 30, 2016. For a discussion of decreases in goodwill associated with the joint venture transactions, see "Goodwill" below.

Property, Plant and Equipment

Property, plant and equipment is recorded at its original cost of construction or, upon acquisition, at the fair value of the assets acquired. The accounting predecessor of Crestwood Equity acquired the accounting predecessor of Crestwood Midstream in October 2010, and accordingly recorded its acquisition of Crestwood Midstream's property, plant and equipment related to its gathering and processing assets in the Barnett Shale at fair value on that date. The resulting increase to Crestwood Midstream's property, plant and equipment was not pushed down by Crestwood Equity to Crestwood Midstream's balance sheet, as permitted by GAAP.

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We evaluate our long-lived assets for impairment whenever events or changes in circumstances indicate that the amount of an asset may not be recoverable. If such events or changes in circumstances are present, a loss is recognized if the carrying value of the asset is in excess of the sum of the undiscounted cash flows expected to result from the use of the asset and its eventual disposition. During 2015, Crestwood Equity recorded a $354.4 million impairment of its property, plant and equipment related to its gathering and processing assets in the Barnett Shale. Crestwood Midstream did not record an impairment of its property, plant and equipment related to its gathering and processing assets in the Barnett Shale as the sum of the undiscounted cash flows expected to result from the use of the assets and their eventual disposition exceeded the carrying value of the property, plant and equipment by over 30%. As a result, Crestwood Midstream's property, plant and equipment exceeds Crestwood Equity's property, plant and equipment related to its gathering and processing assets in the Barnett Shale as of June 30, 2016 and December 31, 2015.

Assets Held for Sale

We classify assets (or groups of assets) to be disposed of as held for sale when specific criteria have been met. Assets classified as held for sale are recorded at the lower of the carrying value or the estimated fair value less cost to sell of those assets . We cease depreciation and amortization of the assets in the period they are considered held for sale.

Goodwill

Our goodwill represents the excess of the amount we paid for a business over the fair value of the net identifiable assets acquired. We evaluate goodwill for impairment annually on December 31, and whenever events indicate that it is more likely than not that the fair value of a reporting unit could be less than its carrying amount. This evaluation requires us to compare the fair value of each of our reporting units to its carrying value (including goodwill). If the fair value exceeds the carrying amount, goodwill of the reporting unit is not considered impaired.

We estimate the fair value of our reporting units based on a number of factors, including discount rates, projected cash flows, and the potential value we would receive if we sold the reporting unit. We also compare the total fair value of our reporting units to our overall enterprise value, which considers the market value for our common and preferred units. Estimating projected cash flows requires us to make certain assumptions as it relates to the future operating performance of each of our reporting units (which includes assumptions, among others, about estimating future operating margins and related future growth in those margins, contracting efforts and the cost and timing of facility expansions) and assumptions related to our customers, such as their future capital and operating plans and their financial condition. When considering operating performance, various factors are considered such as current and changing economic conditions and the commodity price environment, among others. Due to the imprecise nature of these projections and assumptions, actual results can and often do, differ from our estimates. If the assumptions embodied in the projections prove inaccurate, we could incur a future impairment charge. In addition, the use of the income approach to determine the fair value of our reporting units (see further discussion of the use of the income approach below) could result in a different fair value if we had utilized a market approach, or a combination thereof.

We acquired substantially all of our reporting units in 2013, 2012 and 2011, which required us to record the assets, liabilities and goodwill of each of those reporting units at fair value on the date they were acquired. As a result, any level of decrease in the forecasted cash flows of these businesses or increases in the discount rates utilized to value those businesses from their respective acquisition dates would likely result in the fair value of the reporting unit falling below the carrying value of the reporting unit, and could result in an assessment of whether that reporting unit's goodwill is impaired.

Commodity prices have continued to decline since 2014, and that decline has adversely impacted forecasted cash flows, discount rates and stock/unit prices for most companies in the midstream industry, including us. In particular, due to the significant, sustained decrease in the market price of our common units during the first quarter of 2016, we evaluated the carrying value of our reporting units and determined it was more likely than not that the goodwill associated with several of our reporting units was impaired as of March 31, 2016. As a result of further analysis of the fair value of our reporting units, we recorded goodwill impairments on several of our reporting units during the first quarter of 2016. We did not record any goodwill impairments during the three months endedJune 30, 2016.

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The following table summarizes the goodwill of our various reporting units (in millions):

	Goodwill at		Goodwill Impairments during the  Six Months Ended		Deconsolidation of NE S&T Assets at		Goodwill at
	December 31, 2015		June 30, 2016		June 30, 2016		June 30, 2016
Gathering and Processing
Marcellus	$	8.6	$	8.6	$	—	$	—
Arrow	45.9		—		—		45.9
Storage and Transportation
Northeast Storage and Transportation	726.3		—		726.3		—
COLT	44.9		13.7		—		31.2
Marketing, Supply and Logistics					—
Supply and Logistics	167.2		65.5		—		101.7
Storage and Terminals	50.5		14.1		—		36.4
US Salt	12.6		—		—		12.6
Trucking	29.5		7.8		—		21.7
Total	$	1,085.5	$	109.7	$	726.3	$	249.5

The goodwill impairments recorded during the first quarter of 2016 primarily resulted from increasing the discount rates utilized in determining the fair value of the reporting units for certain of those reporting units considering the significant, sustained decrease in the market price of our common units and the continued decrease in commodity prices and its impact on the midstream industry and our customers. Our COLT, Supply and Logistics, Storage and Terminals and Trucking reporting units also experienced impairments during 2015 based on the impact that the prolonged low commodity price environment is expected to have on the demand for future services provided by these operations. Despite increases in the operating results of these reporting units from 2013 to 2015, in light of our modified expectations, we revised our cash flow forecasts for these operations at December 31, 2015 in light of our current view that these operations will not grow as fast or as significantly in the future as originally forecasted in 2013 when the assets were acquired.

The remaining goodwill related to these reporting units represented the fair value of the goodwill, which is a Level 3 fair value measurement. We utilized the income approach to determine the fair value of our reporting units given the limited availability of comparable market-based transactions as of March 31, 2016 and December 31, 2015, and we utilized discount rates ranging from 10% to 19% in applying the income approach to determine the fair value of our reporting units with goodwill as of March 31, 2016.

During the three months endedJune 30, 2015, Crestwood Midstream recorded goodwill impairments of $8.3 million, $28.4 million and $31.9 million related to its Fayetteville, West Coast and Watkins Glen reporting units, respectively. The impairment of the Fayetteville and West Coast goodwill primarily resulted from increasing the discount rate utilized in determining the fair value of the reporting units from 9% to 10%, considering the decrease in commodity prices and its impact on the midstream industry and Crestwood Midstream's customers in those areas. The impairment of the Watkins Glen goodwill primarily resulted from increasing the discount rate utilized in determining the fair value of the reporting unit from 10.5% to 13.3% and delays and uncertainties in the permitting of the proposed storage facility.

In addition to the above goodwill impairments recorded during the three months endedJune 30, 2015, Crestwood Equity recorded a goodwill impairment of its Barnett reporting unit of approximately $212.4 million. The impairment primarily resulted from increasing the discount rate utilized in determining the fair value of the reporting unit from 9% to 11%, considering the recent actions of its primary customer in the Barnett Shale, Quicksilver, related to its filing for protection under Chapter 11 of the U.S. Bankruptcy Code in March 2015.

Deferred Financing Costs

Deferred financing costs represent costs associated with obtaining long-term financing and are amortized over the term of the related debt using a method which approximates the effective interest method and has a weighted average life of six years. Effective January 1, 2016, we adopted the provisions of Accounting Standards Update (ASU) 2015-03, Interest - Imputation of

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Interest (Subtopic 835-30), which requires us to classify our net deferred financing costs of $37.6 million and $40.9 million as a reduction of long-term debt on our consolidated balance sheets at June 30, 2016 and December 31, 2015. Such costs were previously reflected as intangible assets on our consolidated balance sheets.

New Accounting Pronouncements Issued But Not Yet Adopted

As of June 30, 2016, the following accounting standards had not yet been adopted by us:

In May 2014, the Financial Accounting Standards Board (FASB) issued ASU 2014-09, Revenue from Contracts with Customers, which outlines a single comprehensive model for entities to use in accounting for revenue arising from contracts with customers and supersedes current revenue recognition guidance. We expect to adopt the provisions of this standard effective January 1, 2018 and are currently evaluating the method by which we will adopt the standard and the impact that this standard will have on our consolidated financial statements.

In February 2016, the FASB issued ASU 2016-02, Leases (Topic 842), which revises the accounting for leases by requiring certain leases to be recognized as assets and liabilities on the balance sheet, and requiring companies to disclose additional information about their leasing arrangements. We expect to adopt the provisions of this standard effective January 1, 2019 and are currently evaluating the impact that this standard will have on our consolidated financial statements.

In March 2016, the FASB issued ASU 2016-09, Compensation - Stock Compensation (Topic 718):Improvements to Employee Share-Based Payment Accounting, which is intended to improve the accounting for employee share-based payments. The ASU simplifies several aspects of the accounting for share-based payment award transactions, including the classification of awards as either equity or liabilities and presentation on the statement of cash flows. We expect to adopt the provisions of this standard effective January 1, 2017 and are currently evaluating the impact that this standard may have on our consolidated financial statements.

Note 3 – Certain Balance Sheet Information

Assets Held for Sale

In conjunction with the contribution agreement related to Stagecoach Gas, we agreed to contribute our wholly-owned subsidiary, Pipeline East, to Stagecoach Gas, CEGP has agreed to contribute approximately $30 million to Stagecoach Gas, and Stagecoach Gas will distribute to us the net cash proceeds received from CEGP. We classified the property, plant and equipment and goodwill to be contributed to Stagecoach Gas as assets held for sale on our consolidated balance sheet at their fair value at June 30, 2016. The fair value is based on the consideration to be received from the contribution of Pipeline East to Stagecoach Gas and the forecasted discounted cash flows to be received from our investment in Stagecoach Gas, which is a Level 3 fair value measurement. The sale is contingent upon New York State regulatory approval and satisfaction of certain other closing conditions, which we believe is probable at June 30, 2016.

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Accrued Expenses and Other Liabilities

Accrued expenses and other liabilities consisted of the following at June 30, 2016 and December 31, 2015 (in millions):

	CEQP				CMLP
	June 30,		December 31,		June 30,		December 31,
	2016		2015		2016		2015
Accrued expenses	$	35.5	$	46.4	$	33.8	$	44.1
Accrued property taxes	12.3		4.8		7.3		4.8
Accrued product purchases payable	2.8		1.5		2.8		1.5
Tax payable	0.6		0.5		0.6		0.5
Interest payable	23.2		26.2		23.2		26.2
Accrued additions to property, plant and equipment	2.9		10.4		2.9		10.4
Capital leases	1.3		1.6		1.3		1.6
Deferred revenue	22.6		14.2		22.6		14.2
Total accrued expenses and other liabilities	$	101.2	$	105.6	$	94.5	$	103.3

Note 4 - Investments in Unconsolidated Affiliates

Stagecoach Gas Services LLC. In April 2016, Crestwood Northeast and CEGP entered into a definitive agreement to form the Stagecoach JV to own and further develop our NE S&T assets. Pursuant to the contribution agreement, we contributed to Stagecoach Gas the entities owning the NE S&T assets, CEGP contributed $945 million to Stagecoach Gas in exchange for a 50% equity interest in Stagecoach Gas, and Stagecoach Gas distributed to Crestwood Northeast the cash proceeds received (net of approximately $3 million of cash transferred to the joint venture) from CEGP. Effective June 3, 2016, we deconsolidated the NE S&T assets as a result of this transaction and began accounting for our 50% equity interest in Stagecoach Gas under the equity method of accounting, and we reflected our investment at $844 million, which represented the fair value of our proportionate share of the assets at June 3, 2016 and is based on the forecasted discounted cash flows of the investment (which is a Level 3 fair value measurement). We recognized a loss on the deconsolidation of the NE S&T assets of approximately $32.9 million. See our 2015 Annual Report on Form 10-K for a description of our NE S&T assets.

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Net Investments and Earnings

Our net investments in and earnings from our unconsolidated affiliates are as follows (in millions, unless otherwise stated):

	Ownership Percentage			Investment				Earnings (Loss) from Unconsolidated Affiliates
	June 30,			June 30,		December 31,		Three Months Ended June 30,					Six Months Ended June 30,
	2016			2016		2015		2016			2015		2016			2015
Stagecoach Gas Services LLC(1)	50.00	%		$	846.3	$	—	$	2.3		$	—	$	2.3		$	—
Jackalope Gas Gathering Services, L.L.C.(2)	50.00	%	(3)	201.3		202.4		5.9			1.1		11.0			3.6
Tres Palacios Holdings LLC(4)	50.01	%		36.7		36.8		(2.3		)	0.6		(1.5		)	1.5
Powder River Basin Industrial Complex, LLC(5)	50.01	%		14.8		15.1		0.3			3.3		0.9			3.3
Total				$	1,099.1	$	254.3	$	6.2		$	5.0	$	12.7		$	8.4

(1) As of June 30, 2016, our equity in the underlying net assets of Stagecoach Gas exceeded our investment balance by approximately $50.8 million. Our Stagecoach Gas investment is included in our storage and transportation segment.

(2) As of June 30, 2016, our equity in the underlying net assets of Jackalope Gas Gathering Services, L.L.C. (Jackalope) exceeded our investment balance by approximately $0.8 million. We amortize this amount over 20 years, which represents the life of Jackalope’s gathering agreement with Chesapeake Energy Corporation (Chesapeake), and we reflect the amortization as an increase in our earnings from unconsolidated affiliates. We recorded amortization of less than $0.1 million for both the three and six months endedJune 30, 2016 and $0.7 million and $1.5 million for the three and six months endedJune 30, 2015. Our Jackalope investment is included in our gathering and processing segment.

(3) Excludes non-controlling interests related to our investment in Jackalope. See Note 9 for a further discussion of our non-controlling interest related to our investment in Jackalope.

(4) As of June 30, 2016, our equity in the underlying net assets of Tres Palacios Holdings LLC (Tres Holdings) exceeded our investment balance by approximately $28.5 million. We amortize this amount over the life of the Tres Palacios Gas Storage LLC (Tres Palacios) sublease agreement, and we reflect the amortization as an increase in our earnings from unconsolidated affiliates. We recorded amortization of $0.3 million for the three months endedJune 30, 2016 and 2015, and $0.6 million for the six months endedJune 30, 2016 and 2015. Our Tres Holdings investment is included in our storage and transportation segment.

(5) As of June 30, 2016, our equity in the underlying net assets of PRBIC exceeded our investment balance by approximately $22.6 million. We amortize a portion of this amount over the life of PRBIC's property, plant and equipment and its agreement with Chesapeake, and we reflect the amortization as an increase in our earnings from unconsolidated affiliates. Approximately $10.6 million of this excess amount relates to goodwill and, as such, is not subject to amortization. We recorded amortization of approximately $0.4 million and $0.8 million for the three and six months endedJune 30, 2016. During the three and six months ended June 30, 2015, we recorded additional equity earnings of approximately $3.2 million related to a gain associated with the adjustment of our member's capital account by our equity investee. Our PRBIC investment is included in our storage and transportation segment.

Distributions and Contributions

Stagecoach Gas. Stagecoach Gas is required, within 30 days following the end of each quarter, to distribute 65% and 35% of its available cash (as defined in its limited liability company agreement) to CEQP and us, respectively. Because our ownership and distribution percentages differ, we determine the equity earnings from Stagecoach Gas using the Hypothetical Liquidation at Book Value (HLBV) method. Under the HLBV method, a calculation is prepared at each balance sheet date to determine the amount that we would receive if Stagecoach Gas were to liquidate all of its assets, as valued in accordance with GAAP, and distribute that cash to the members. The difference between the calculated liquidation distribution amounts at the beginning and the end of the reporting period, after adjusting for capital contributions and distributions, is our share of the earnings or losses from the equity investment for the period, which approximates how earnings are allocated under the terms of the limited liability company agreement. In July 2016, we received a cash distribution of approximately $3.7 million from Stagecoach Gas.

Jackalope.Jackalope is required, within 30 days following the end of each quarter, to make quarterly distributions of its available cash to its members based on their respective ownership percentage. During the six months endedJune 30, 2016 and 2015, we received cash distributions of approximately $12.1 million and $4.5 million from Jackalope. During the six months endedJune 30, 2015, we contributed approximately $17.9 million to Jackalope.

Tres Holdings. Tres Holdings is required, within 30 days following the end of each quarter, to make quarterly distributions of its available cash (as defined in its limited liability company agreement) to its members based on their respective ownership percentage. During the six months endedJune 30, 2016 and 2015, we received cash distributions of approximately $4.1 million and $2.1 million from Tres Holdings. In July 2016, we received a cash distribution of approximately $2.1 million from Tres

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Holdings. During the six months endedJune 30, 2016 and 2015, we contributed approximately $5.5 million and $5.7 million to Tres Holdings.

PRBIC. PRBIC is required to make quarterly distributions of its available cash to its members based on their respective ownership percentage. During the six months endedJune 30, 2016 and 2015, we received cash distributions of approximately $1.2 million and $0.7 million from PRBIC. In July 2016, we received a cash distribution of approximately $0.4 million from PRBIC. During the six months endedJune 30, 2015, we contributed approximately $4.2 million to PRBIC.

Note 5 – Risk Management

We are exposed to certain market risks related to our ongoing business operations. These risks include exposure to changing commodity prices. We utilize derivative instruments to manage our exposure to fluctuations in commodity prices, which is discussed below. Additional information related to our derivatives is discussed in Note 6.

Commodity Derivative Instruments and Price Risk Management

Risk Management Activities

We sell NGLs to energy related businesses and may use a variety of financial and other instruments including forward contracts involving physical delivery of NGLs, heating oil and crude oil. We periodically enter into offsetting positions to economically hedge against the exposure our customer contracts create. Certain of these contracts and positions are derivative instruments. We do not designate any of our commodity-based derivatives as hedging instruments for accounting purposes. Our commodity-based derivatives are reflected at fair value in the consolidated balance sheets, and changes in the fair value of these derivatives that impact the consolidated statements of operations are reflected in costs of product/services sold. During the three and six months endedJune 30, 2016, the impact to the statement of operations related to our commodity-based derivatives reflected in costs of product/services sold was a gain of $1.3 million and $2.0 million. During the three and six months endedJune 30, 2015, the impact to the statement of operations related to our commodity-based derivatives reflected in costs of product/services sold was a gain of $2.9 million and $5.3 million. We attempt to balance our contractual portfolio in terms of notional amounts and timing of performance and delivery obligations. This balance in the contractual portfolio significantly reduces the volatility in costs of product/services sold related to these instruments.

Commodity Price and Credit Risk

Notional Amounts and Terms

The notional amounts and terms of our derivative financial instruments include the following at June 30, 2016 and December 31, 2015 (in millions):

	June 30, 2016		December 31, 2015
	Fixed Price Payor	Fixed Price Receiver	Fixed Price Payor	Fixed Price Receiver
Propane, crude and heating oil (barrels)	12.4	13.8	9.1	10.9

Notional amounts reflect the volume of transactions, but do not represent the amounts exchanged by the parties to the financial instruments. Accordingly, notional amounts do not reflect our monetary exposure to market or credit risks.

All contracts subject to price risk had a maturity of 34 months or less; however, 82% of the contracted volumes will be delivered or settled within 12 months.

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Credit Risk

Inherent in our contractual portfolio are certain credit risks. Credit risk is the risk of loss from nonperformance by suppliers, customers or financial counterparties to a contract. We take an active role in managing credit risk and have established control procedures, which are reviewed on an ongoing basis. We attempt to minimize credit risk exposure through credit policies and periodic monitoring procedures as well as through customer deposits, letters of credit and entering into netting agreements that allow for offsetting counterparty receivable and payable balances for certain financial transactions, as deemed appropriate. The counterparties associated with our assets from price risk management activities as of June 30, 2016 and December 31, 2015 were energy marketers and propane retailers, resellers and dealers.

Certain of our derivative instruments have credit limits that require us to post collateral. The amount of collateral required to be posted is a function of the net liability position of the derivative as well as our established credit limit with the respective counterparty. If our credit rating were to change, the counterparties could require us to post additional collateral. The amount of additional collateral that would be required to be posted would vary depending on the extent of change in our credit rating as well as the requirements of the individual counterparty. The aggregate fair value of all commodity derivative instruments with credit-risk-related contingent features that were in a liability position at June 30, 2016 and December 31, 2015 was $5.5 million and $3.3 million. At June 30, 2016 and December 31, 2015, we posted less than $0.1 million of collateral for our commodity derivative instruments with credit-risk-related contingent features. In addition, at June 30, 2016 and December 31, 2015, we had a New York Mercantile Exchange (NYMEX) related net derivative liability position of $9.3 million and $20.8 million, for which we posted $6.1 million and $26.7 million of cash collateral in the normal course of business. At June 30, 2016 and December 31, 2015, we also received collateral of $5.0 million and $16.8 million in the normal course of business. All collateral amounts have been netted against the asset or liability with the respective counterparty and are reflected in our consolidated balance sheets as assets and liabilities from price risk management activities.

Note 6 – Fair Value Measurements

The accounting standards for fair value measurement establish a three-tier fair value hierarchy, which prioritizes the inputs used in measuring fair value. The hierarchy gives the highest priority to unadjusted quoted prices in active markets for identical assets or liabilities (Level 1 measurement) and the lowest priority to unobservable inputs (Level 3 measurement). The three levels of the fair value hierarchy are as follows:

• Level 1—Quoted prices are available in active markets for identical assets or liabilities as of the reporting date. Active markets are those in which transactions for the asset or liability occur in sufficient frequency and volume to provide pricing information on an ongoing basis. Level 1 primarily consists of financial instruments such as exchange-traded derivatives, listed equities and US government treasury securities.

• Level 2—Pricing inputs are other than quoted prices in active markets included in Level 1, which are either directly or indirectly observable as of the reporting date. Level 2 includes those financial instruments that are valued using models or other valuation methodologies. These models are primarily industry-standard models that consider various assumptions, including quoted forward prices for commodities, time value, volatility factors, and current market and contractual prices for the underlying instruments, as well as other relevant economic measures. Substantially all of these assumptions are observable in the marketplace throughout the full term of the instrument, can be derived from observable data or are supported by observable levels at which transactions are executed in the marketplace. Instruments in this category include non-exchange-traded derivatives such as over the counter (OTC) forwards, options and physical exchanges.

• Level 3—Pricing inputs include significant inputs that are generally less observable from objective sources. These inputs may be used with internally developed methodologies that result in management’s best estimate of fair value.

Cash and Cash Equivalents, Accounts Receivable and Accounts Payable

As of June 30, 2016 and December 31, 2015, the carrying amounts of cash, accounts receivable and accounts payable represent fair value based on the short-term nature of these instruments.

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Credit Facility

The fair value of the amount outstanding under our CMLP credit facility approximates its carrying amount as of June 30, 2016 and December 31, 2015, due primarily to the variable nature of the interest rate of the instrument, which is considered a Level 2 fair value measurement.

Senior Notes

We estimate the fair value of our senior notes primarily based on quoted market prices for the same or similar issuances (representing a Level 2 fair value measurement). The following table reflects the carrying value and fair value of our CMLP senior notes (in millions):

	June 30, 2016				December 31, 2015
	Carrying  Amount		Fair Value		Carrying  Amount		Fair Value
Crestwood Midstream 2020 Senior Notes	$	340.8	$	319.9	$	503.3	$	382.3
Crestwood Midstream 2022 Senior Notes	$	436.4	$	400.8	$	600.0	$	437.4
Crestwood Midstream 2023 Senior Notes	$	700.0	$	645.8	$	700.0	$	491.8

Financial Assets and Liabilities

As of June 30, 2016 and December 31, 2015, we held certain assets and liabilities that are required to be measured at fair value on a recurring basis, which include our derivative instruments related to heating oil, crude oil, and NGLs. Our derivative instruments consist of forwards, swaps, futures, physical exchanges and options.

Certain of our derivative instruments are traded on the NYMEX. These instruments have been categorized as Level 1.

Our derivative instruments also include OTC contracts, which are not traded on a public exchange. The fair values of these derivative instruments are determined based on inputs that are readily available in public markets or can be derived from information available in publicly quoted markets. These instruments have been categorized as Level 2.

Our OTC options are valued based on the Black Scholes option pricing model that considers time value and volatility of the underlying commodity. The inputs utilized in the model are based on publicly available information as well as broker quotes. These options have been categorized as Level 2.

Our financial assets and liabilities are classified in their entirety based on the lowest level of input that is significant to the fair value measurement. The assessment of the significance of a particular input to the fair value measurement requires judgment, and may affect the valuation of fair value assets and liabilities and their placement within the fair value hierarchy levels.

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The following tables set forth by level within the fair value hierarchy, our financial instruments that were accounted for at fair value on a recurring basis at June 30, 2016 and December 31, 2015 (in millions):

	June 30, 2016
	Fair Value of Derivatives
	Level 1		Level 2		Level 3		Gross Fair Value		Contract Netting(1)			Collateral/Margin Received or Paid			Recorded in Balance Sheet
Assets
Assets from price risk management	$	0.2	$	44.0	$	—	$	44.2	$	(28.9	)	$	(5.8	)	$	9.5
Suburban Propane Partners, L.P. units(2)	4.7		—		—		4.7		—			—			4.7
Total assets at fair value	$	4.9	$	44.0	$	—	$	48.9	$	(28.9	)	$	(5.8	)	$	14.2
Liabilities
Liabilities from price risk management	$	0.2	$	37.5	$	—	$	37.7	$	(28.9	)	$	2.1		$	10.9
Total liabilities at fair value	$	0.2	$	37.5	$	—	$	37.7	$	(28.9	)	$	2.1		$	10.9
	December 31, 2015
	Fair Value of Derivatives
	Level 1		Level 2		Level 3		Gross Fair Value		Contract Netting(1)			Collateral/Margin Received or Paid			Recorded in Balance Sheet
Assets
Assets from price risk management	$	0.5	$	57.8	$	—	$	58.3	$	(13.7	)	$	(12.0	)	$	32.6
Suburban Propane Partners, L.P. units(2)	3.4		—		—		3.4		—			—			3.4
Total assets at fair value	$	3.9	$	57.8	$	—	$	61.7	$	(13.7	)	$	(12.0	)	$	36.0
Liabilities
Liabilities from price risk management	$	0.2	$	41.3	$	—	$	41.5	$	(13.7	)	$	(20.4	)	$	7.4
Total liabilities at fair value	$	0.2	$	41.3	$	—	$	41.5	$	(13.7	)	$	(20.4	)	$	7.4

(1) Amounts represent the impact of legally enforceable master netting agreements that allow us to settle positive and negative positions as well as cash collateral held or placed with the same counterparties.

(2) Amount is reflected in other assets on CEQP's consolidated balance sheets.

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Note 7 – Long-Term Debt

Long-term debt consisted of the following at June 30, 2016 and December 31, 2015 (in millions):

	June 30, 2016		December 31, 2015
Credit Facility	$	139.0	$	735.0
2020 Senior Notes	338.8		500.0
Fair value adjustment of 2020 Senior Notes	2.0		3.3
2022 Senior Notes	436.4		600.0
2023 Senior Notes	700.0		700.0
Other	3.9		5.3
Less: deferred financing costs, net	37.6		40.9
Total Crestwood Midstream debt	1,582.5		2,502.7
Other	—		0.2
Total Crestwood Equity debt	1,582.5		2,502.9
Less: current portion	0.9		1.1
Total long-term debt, less current portion	$	1,581.6	$	2,501.8

Crestwood Midstream Credit Facility

In conjunction with the contribution agreement with CEGP, Crestwood Midstream amended its credit facility during the second quarter of 2016 to, among other things, (i) facilitate the closing of the joint venture and make investments in the joint venture thereafter, and (ii) implement our liability management plan with the net cash proceeds received from Stagecoach Gas, including the repurchase of Crestwood Midstream's senior notes with the borrowings under its credit facility.

At June 30, 2016, Crestwood Midstream had $613.9 million of available capacity under its credit facility considering the most restrictive debt covenants in its credit agreement. At June 30, 2016 and December 31, 2015, Crestwood Midstream's outstanding standby letters of credit were $62.1 million and $62.2 million. Borrowings under the CMLP credit facility accrue interest at prime or Eurodollar based rates plus applicable spreads, which resulted in interest rates between 3.21% and 5.25% at June 30, 2016 and 2.70% and 5.00% at December 31, 2015. The weighted-average interest rate as of June 30, 2016 and December 31, 2015 was 3.30% and 2.70%.

Crestwood Midstream is required under its credit agreement to maintain a net debt to consolidated EBITDA ratio (as defined in its credit agreement) of not more than 5.50 to 1.0, a consolidated EBITDA to consolidated interest expense ratio (as defined in its credit agreement) of not less than 2.50 to 1.0, and a senior secured leverage ratio (as defined in its credit agreement) of not more than 3.75 to 1.0. At June 30, 2016, the net debt to consolidated EBITDA was approximately 3.99 to 1.0, the consolidated EBITDA to consolidated interest expense was approximately 3.82 to 1.0, and the senior secured leverage ratio was 0.34 to 1.0.

Crestwood Midstream Senior Notes

In June 2016, Crestwood Midstream paid approximately $312.9 million to purchase and cancel approximately $161.2 million and $163.6 million of the principal amounts outstanding under its 2020 Senior Notes and 2022 Senior Notes, respectively, utilizing a portion of the proceeds received from Stagecoach Gas, as further discussed in Note 2.  Crestwood Midstream recognized a gain on extinguishment of debt of approximately $10.0 million in conjunction with the early tender of these notes. Crestwood Midstream also paid $4.5 million and $2.6 million of accrued interest on the 2020 Senior Notes and 2022 Senior Notes, respectively, on the date they were tendered.

In March 2016, Crestwood Midstream filed a registration statement with the SEC under which it plans to offer to exchange $700.0 million of its 6.25% 2023 Senior Notes for any and all outstanding notes. The exchange offer was declared effective by the SEC on June 15, 2016 and closed on July 13, 2016. The terms of the exchange notes are substantially identical to the terms of the 2023 Senior Notes, except that the exchange notes are freely tradable. Crestwood Midstream issued the 2023 Senior Notes in March 2015. The net proceeds from the original offering of approximately $688.3 million were used to pay down borrowings under Crestwood Midstream's credit facility and for general partnership purposes.

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At June 30, 2016, Crestwood Midstream was in compliance with all of its debt covenants applicable to the CMLP credit facility and its senior notes.

Note 8 - Earnings Per Limited Partner Unit

Our net income (loss) attributable to Crestwood Equity Partners is allocated to the subordinated and limited partner unitholders based on their ownership percentage after giving effect to net income attributable to the Class A preferred units. We calculate basic net income per limited partner unit using the two-class method. Diluted net income per limited partner unit is computed using the treasury stock method, which considers the impact to net income attributable to Crestwood Equity Partners and limited partner units from the potential issuance of limited partner units.

We exclude potentially dilutive securities from the determination of diluted earnings per unit (as well as their related income statement impacts) when their impact on net income attributable to Crestwood Equity Partners per limited partner unit is anti-dilutive. During the three and six months endedJune 30, 2016, we excluded a weighted-average of 6,355,936 and 6,284,885 common units (representing preferred units), a weighted-average of 438,789 common units in both periods (representing subordinated units), and a weighted-average of 8,438,849 common units in both periods (representing Crestwood Niobrara's preferred units). See Note 9 for additional information regarding the potential conversion of our preferred units and Crestwood Niobrara's preferred units to common units. There were no units excluded from our dilutive earnings per unit as we did not have any anti-dilutive units for the three and six months endedJune 30, 2015 .

Note 9 – Partners’ Capital

Distributions

Crestwood Equity

Limited Partners. A summary of CEQP's limited partner quarterly cash distributions for the six months endedJune 30, 2016 and 2015 is presented below:

Record Date	Payment Date	Per Unit Rate		Cash Distributions (in millions)
2016
February 5, 2016	February 12, 2016	$	1.375	$	95.6
May 6, 2016	May 13, 2016	0.60		41.4
				$	137.0
2015
February 6, 2015	February 13, 2015	$	1.375	$	25.8
May 8, 2015	May 15, 2015	1.375		25.7
				$	51.5

On July 21, 2016,we declared a distribution of $0.60 per limited partner unit to be paid on August 12, 2016, to unitholders of record on August 5, 2016 with respect to the second quarter of 2016.

Preferred Unit Holders. In conjunction with the closing of the Simplification Merger, the CMLP Class A Preferred Units were exchanged for new preferred units of the Company (the Preferred Units) with substantially similar terms and conditions to those of the CMLP Preferred Units. We are required to make quarterly distributions to our preferred unitholders. During the six months endedJune 30, 2016, we issued 2,841,114 Preferred Units to our preferred unitholders in lieu of paying cash distributions of $25.9 million. On July 21, 2016, the board of directors of our general partner authorized the issuance of 1,470,029 Preferred Units to our preferred unit holders for the quarter ended June 30, 2016 in lieu of paying a cash distribution of $13.4 million.

On June 9, 2016, Crestwood Equity filed a shelf registration statement with the SEC under which holders of the Preferred Units may sell the common units into which the Preferred Units are convertible. The registration statement became effective on June 15, 2016. Crestwood Equity registered 7,290,552 common units under the registration statement.

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Crestwood Midstream

Prior to the Simplification Merger, the Company indirectly owned a non-economic general partnership interest in Crestwood Midstream and 100% of its incentive distribution rights (IDRs). Crestwood Midstream was also a publicly-traded limited partnership with common units listed on the NYSE. However, as a result of Crestwood Midstream's completion of the Simplification Merger on September 30, 2015, its common units ceased to be listed on the NYSE, the IDRs were eliminated and Crestwood Midstream became a wholly-owned subsidiary of the Company.

During the six months endedJune 30, 2016 and 2015, Crestwood Midstream paid cash distributions of $140.6 million and $51.9 million to Crestwood Equity. During the six months endedJune 30, 2015, Crestwood Midstream paid a cash distribution to its general partner (representing IDRs and distributions related to common units held by the general partner) of approximately $20.9 million.

Limited Partners. The following table presents quarterly cash distributions paid to Crestwood Midstream's limited partners (excluding distributions paid to its general partner on its common units held) during the six months endedJune 30, 2015.

Record Date	Payment Date	Per Unit Rate		Cash Distributions (in millions)
February 6, 2015	February 13, 2015	$	0.41	$	74.3
May 8, 2015	May 15, 2015	0.41		74.3
				$	148.6

Non-Controlling Partners

Crestwood Midstream Class A Preferred Units

As discussed above, in conjunction with the closing of the Simplification Merger, the CMLP Class A Preferred Units were exchanged for new preferred units of Crestwood Equity. Prior to the Simplification Merger, Crestwood Equity classified the CMLP Class A Preferred Units as a component of Interest of Non-Controlling Partners on its consolidated balance sheet.

Crestwood Niobrara Preferred Interest

Crestwood Niobrara issued a preferred interest to a subsidiary of General Electric Capital Corporation and GE Structured Finance, Inc. (collectively, GE) in conjunction with the acquisition of its investment in Jackalope, which is reflected as non-controlling interest in our consolidated financial statements.

Net Income (Loss) Attributable to Non-Controlling Partners

The components of net income (loss) attributable to non-controlling partners for the three and six months endedJune 30, 2016 and 2015, are as follows (in millions):

	Three Months Ended					Six Months Ended
	June 30,					June 30,
	2016		2015			2016		2015
Crestwood Niobrara preferred interests	$	6.0	$	5.7		$	11.9	$	11.3
CMLP net income attributable to non-controlling partners	6.0		5.7			11.9		11.3
Crestwood Midstream limited partner interests	—		(269.2		)	—		(274.2		)
Crestwood Midstream Class A preferred units	—		7.5			—		16.7
CEQP net income (loss) attributable to non-controlling partners	$	6.0	$	(256.0	)	$	11.9	$	(246.2	)

Distributions to Non-Controlling Partners

Crestwood Midstream Limited Partners. As discussed above, Crestwood Midstream paid cash distributions to its limited partners (excluding distributions to its general partner and distributions on the limited partner units that were owned by Crestwood Equity) of $148.6 million during the six months endedJune 30, 2015.

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Crestwood Midstream Class A Preferred Unit Holders. During the six months endedJune 30, 2015, Crestwood Midstream issued 838,228 Class A Preferred Units to its preferred unit holders in lieu of paying cash distributions of $21.0 million.

Crestwood Niobrara Preferred Unit Holders. During the six months endedJune 30, 2016 and 2015, Crestwood Niobrara paid cash distributions of $7.6 million and $3.8 million to GE. In July 2016, Crestwood Niobrara paid a cash distribution of $3.8 million to GE for the quarter ended June 30, 2016.

Note 10 – Commitments and Contingencies

Legal Proceedings

Canadian Class Action Lawsuit. Prior to the completion of our acquisition of Arrow Midstream Holdings, LLC (Arrow) on November 8, 2013, a train transporting over 50,000 barrels of crude oil produced in North Dakota derailed in Lac Megantic, Quebec, Canada on July 6, 2013. The derailment resulted in the death of 47 people, injured numerous others, and caused severe damage to property and the environment.  In October 2013, certain individuals suffering harm in the derailment filed a motion to certify a class action lawsuit in the Superior Court for the District of Megantic, Province of Quebec, Canada, on behalf of all persons suffering loss in the derailment (the Class Action Suit).

In March 2014, the plaintiffs filed their fourth amended motion to name Arrow and numerous other energy companies as additional defendants in the class action lawsuit. The plaintiffs alleged, among other things, that Arrow (i) was a producer of the crude oil being transported on the derailed train, (ii) was negligent in failing to properly classify the crude delivered to the trucks that hauled the crude to the rail loading terminal, and (iii) owed a duty to the petitioners to ensure the safe transportation of the crude being transported.  The motion to authorize the class action and motions in opposition were heard by the Court in June 2014. In June 2015, the Superior Court determined that the Class Action Suit proceeding should be allowed to proceed against certain respondents that have not contributed to the global settlement described below. Because Arrow is a contributing party to the global settlement, the Class Action Suit against Arrow was stayed pending finalization of the global settlement plan in the United States and Canadian bankruptcy proceedings described below.

One of the defendants in the lawsuit, Montreal Main & Atlantic Railway (MM&A), filed bankruptcy actions in the U.S. Bankruptcy Court for the District of Maine and in the Canadian Bankruptcy Court. The bankruptcy trustees in the proceedings approached the respondents in the Class Action Suit (including Arrow) to contribute monetary damages to a global settlement for all claims, including any potential environmental damages, related to the Lac Megantic derailment. Crestwood Midstream agreed to contribute to the global settlement in exchange for a release from all claims related to the derailment, including the Class Action Suit. The Canadian and United States bankruptcy courts approved the bankruptcy plan (including the global settlement which was funded in December 2015). Crestwood Midstream's contribution to the global settlement, in addition to associated legal fees, is fully covered by insurance, and since the global settlement is finalized, Arrow should not be exposed to additional damages relating to the derailment.

Additional lawsuits related to the derailment were filed in United States courts but were stayed as a result of the automatic stay arising from MM&A's United States bankruptcy proceeding. Arrow was named as a defendant in 39 lawsuits pending in three different courts; however, these lawsuits were dismissed with prejudice upon disbursement of funds to the victims. The settlement of the bankruptcy proceedings and the dismissals of the Class Action Suit and United States lawsuits did not have a material impact on our consolidated results of operations after considering insurance.

Simplification Merger Lawsuits. On May 20, 2015, Lawrence G. Farber, a purported unitholder of Crestwood Midstream, filed a complaint in the Southern District of the United States, Houston Division, as a putative class action on behalf of Crestwood Midstream's unitholders, entitled Lawrence G. Farber, individually and on behalf of all others similarly situated v. Crestwood Midstream Partners LP, Crestwood Midstream GP LLC, Robert G. Phillips, Alvin Bledsoe, Michael G. France, Philip D. Gettig, Warren H. Gfellar, David Lumpkins, John J. Sherman, David Wood, Crestwood Equity Partners LP, Crestwood Equity GP LLC, CEQP ST Sub LLC, MGP GP, LLC, Crestwood Midstream Holdings LP, and Crestwood Gas Services GP LLC. This complaint alleges, among other things, that Crestwood Midstream's general partner breached its fiduciary duties, certain individual defendants breached their fiduciary duties of loyalty and due care, and that other defendants aided and abetted such breaches.

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On July 21, 2015, Isaac Aron, another purported unitholder of the Crestwood Midstream, filed a complaint in the Southern District of the United States, Houston Division, as a putative class action on behalf of Crestwood Midstream's unitholders, entitled Isaac Aron, individually and on behalf of all others similarly situated vs. Robert G. Phillps, Alvin Bledsoe, Michael G. France, Philip D. Getting, Warren H. Gfeller, David Lumpkins, John J. Sherman, David Wood, Crestwood Midstream Partners, LP Crestwood Midstream Holdings LP, Crestwood Midstream GP LLC, Crestwood Gas Services GP, LLC, Crestwood Equity Partners LP, Crestwood Equity GP LLC, CEQP ST Sub LLC and MGP GP, LLC. The complaint alleges, among other things, that Crestwood Midstream's general partner and certain individual defendants violated Sections 14(a) and 20(a) of the Securities Exchange Act of 1934 and Rule 14a-9 by filing an alleged incomplete and misleading Form S-4 Registration Statement with the SEC.

On August 12, 2015, the defendants filed a motion to consolidate the Farber and Aron cases, which the court granted on September 4, 2015. Farber subsequently dismissed his claims against all the defendants on September 16, 2015. Aron filed a motion for temporary restraining order and requested an expedited preliminary injunction hearing, which had been scheduled for September 23, 2015. On September 22, 2015, however, the parties entered into a memorandum of understanding (MOU) with respect to a proposed settlement of the Aron lawsuit. The settlement contemplated by the MOU is subject to a number of conditions, including notice to the class, limited confirmatory discovery and final court approval of the settlement. A hearing is scheduled for October 7, 2016 regarding the plaintiff's motion to approve the settlement. The anticipated settlement of the MOU has not and will not have a material impact to our consolidated financial statements.

Property Taxes. Tres Palacios filed a lawsuit in Matagorda County for tax years 2011, 2012 and 2013 alleging that the Matagorda County Appraisal District (MCAD) assessed taxable value above the fair market value and on an unequal and non-uniform basis compared to other properties. In conjunction with its sale of Tres Palacios to Tres Holdings, Crestwood Equity retained liability for certain tax matters, including this litigation. In January 2015, Crestwood Equity received a refund related to the 2011 tax year at the conclusion of the litigation related to that tax year. For the 2012 and 2013 tax years, the MCAD asserted a taxable value that would result in property taxes of approximately $7 million for each of those years, while Tres Palacios asserted a taxable value that would result in property taxes of less than $2 million in each year. Tres Palacios paid approximately $8.6 million to Matagorda County in total for those two tax years. A bench trial was held in October 2015 related to the 2012 and 2013 tax years. In June 2016, the court issued a final judgment on the 2012 and 2013 property tax years which resulted in Crestwood Equity recording additional net property taxes (including interest and penalties) of approximately $3.5 million during the three months endedJune 30, 2016. Crestwood Equity has filed a motion for a new trial.

General. We are periodically involved in litigation proceedings. If we determine that a negative outcome is probable and the amount of loss is reasonably estimable, then we accrue the estimated amount. The results of litigation proceedings cannot be predicted with certainty. We could incur judgments, enter into settlements or revise our expectations regarding the outcome of certain matters, and such developments could have a material adverse effect on our results of operations or cash flows in the period in which the amounts are paid and/or accrued. As of June 30, 2016 and December 31, 2015, both CEQP and CMLP had less than $0.1 million accrued for outstanding legal matters. Based on currently available information, we believe it is remote that future costs related to known contingent liability exposures for which we can estimate will exceed current accruals by an amount that would have a material adverse impact on our consolidated financial statements. As we learn new facts concerning contingencies, we reassess our position both with respect to accrued liabilities and other potential exposures.

Any loss estimates are inherently subjective, based on currently available information, and are subject to management's judgment and various assumptions. Due to the inherently subjective nature of these estimates and the uncertainty and unpredictability surrounding the outcome of legal proceedings, actual results may differ materially from any amounts that have been accrued.

Regulatory Compliance

In the ordinary course of our business, we are subject to various laws and regulations. In the opinion of our management, compliance with current laws and regulations will not have a material effect on its results of operations, cash flows or financial condition.

Environmental Compliance

During 2014, we experienced three releases totaling approximately 28,000 barrels of produced water on our Arrow water gathering system located on the Fort Berthold Indian Reservation in North Dakota. We immediately notified the National Response Center, the Three Affiliated Tribes and numerous other regulatory authorities, and thereafter contained and cleaned up the releases completely and placed the impacted segments of these water lines back into service. In May 2015, we experienced

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a release of approximately 5,200 barrels of produced water on our Arrow water gathering system, immediately notified numerous regulatory authorities and other third parties, and thereafter contained and cleaned up the releases.  We will continue our remediation efforts to ensure the impacted lands are restored to their prior state. We believe these releases are insurable events under our policies, and we have notified our carriers of these events. We have not recorded an insurance receivable as of June 30, 2016.

We may potentially be subject to fines and penalties as a result of the water releases.  In October 2014, we received data requests from the Environmental Protection Agency (EPA) related to the 2014 water releases and we responded to the requests during the first half of 2015.  In April 2015, the EPA issued a Notice of Potential Violation (NOPV) under the Clean Water Act relating to the 2014 water releases. We responded to the NOPV in May 2015, and have commenced settlement discussions with the EPA concerning the NOPV. On March 3, 2015, we received a grand jury subpoena from the United States Attorney’s Office in Bismarck, North Dakota, seeking documents and information relating to the largest of the three 2014 water releases, and we provided the requested information during the second quarter of 2015. In August 2015, we received a notice of violation from the Three Affiliated Tribes' Environmental Division related to our 2014 produced water releases on the Fort Berthold Indian Reservation. The notice of violation imposes fines and requests reimbursements exceeding $1.1 million; however, the notice of violation was stayed on September 15, 2015, upon our posting of a performance bond for the amount contemplated by the notice and pending the outcome of ongoing settlement discussions with the regulatory agencies asserting jurisdiction over the 2014 produced water releases. We cannot predict what the outcome of these investigations will be.

Our operations are subject to stringent and complex laws and regulations pertaining to health, safety, and the environment. We are subject to laws and regulations at the federal, state and local levels that relate to air and water quality, hazardous and solid waste management and disposal and other environmental matters. The cost of planning, designing, constructing and operating our facilities must incorporate compliance with environmental laws and regulations and safety standards. Failure to comply with these laws and regulations may trigger a variety of administrative, civil and potentially criminal enforcement measures. At June 30, 2016 and December 31, 2015, our accrual of approximately $2.6 million and $1.7 million is based on our undiscounted estimate of amounts we will spend on compliance with environmental and other regulations, and any associated fines or penalties. We estimate that our potential liability for reasonably possible outcomes related to our environmental exposures (including the Arrow water releases described above) could range from approximately $2.6 million to $4.9 million at June 30, 2016.

Self-Insurance

We utilize third-party insurance subject to varying retention levels of self-insurance, which management considers prudent. Such self-insurance relates to losses and liabilities primarily associated with medical claims, workers' compensation claims and general, product, vehicle and environmental liability. At June 30, 2016 and December 31, 2015, CEQP's self-insurance reserves were $17.8 million and $17.2 million. We estimate that $11.3 million of this balance will be paid subsequent to June 30, 2017. As such, CEQP has classified $11.3 million in other long-term liabilities on its consolidated balance sheet at June 30, 2016. At June 30, 2016 and December 31, 2015, CMLP's self insurance reserves were $12.4 million and $11.4 million. CMLP estimates that $7.1 million of this balance will be paid subsequent to June 30, 2017. As such, CMLP has classified $7.1 million in other long-term liabilities on its consolidated balance sheet at June 30, 2016.

Note 11 – Related Party Transactions

CEQP and CMLP enter into transactions with their affiliates within the ordinary course of business and the services are based on the same terms as non-affiliates, including gas gathering and processing services under long-term contracts, product purchases and various operating agreements.

In May 2016, Crestwood Midstream Operations, LLC (Crestwood Midstream Operations), our wholly-owned subsidiary and Stagecoach Gas entered into a management agreement under which Crestwood Midstream Operations will provide the management and operating services required by Stagecoach Gas' facilities. The initial term of the agreement will expire in May 2021, and is automatically extended for three-year periods unless otherwise terminated pursuant to the terms of the agreement. During the three and six months endedJune 30, 2016, we charged Stagecoach Gas $0.3 million under this agreement, which is reflected as operations and maintenance expenses charged by CEQP and CMLP in the table below.

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The following table shows revenues, costs of product/services sold, general and administrative expenses and reimbursements of expenses from our affiliates for the three and six months endedJune 30, 2016 and 2015 (in millions):

	Three Months Ended					Six Months Ended
	June 30,					June 30,
	2016			2015		2016			2015
Gathering and processing revenues at CEQP and CMLP	$	0.7		$	1.1	$	1.4		$	2.1
Gathering and processing costs of product/services sold at CEQP and CMLP(1)	$	4.4		$	7.7	$	8.7		$	16.0
Operations and maintenance expenses charged by CEQP and CMLP	$	1.0		$	0.7	$	1.7		$	1.6
General and administrative expenses charged by CEQP to CMLP, net(2)	$	3.2		$	14.4	$	6.9		$	31.8
General and administrative expenses charged by (from) CEQP to Crestwood Holdings, net(3)	$	(0.2	)	$	0.1	$	(0.1	)	$	0.2

(1) Represents natural gas purchases from Sabine Oil and Gas Corporation.

(2) Includes $3.9 million and $8.4 million of net unit-based compensation charges allocated from CEQP to CMLP for the three and six months endedJune 30, 2016 and $2.2 million and $4.4 million for the three and six months endedJune 30, 2015. In addition, prior to the completion of the Simplification Merger, CEQP allocated general and administrative costs to CMLP. In conjunction with the Simplification Merger, CMLP shares common management, general and administrative and overhead costs with CEQP. During the three and six months endedJune 30, 2016, CMLP allocated $0.7 million and $1.5 million of general and administrative costs to CEQP.

(3) Includes $0.9 million unit-based compensation charges allocated from Crestwood Holdings to CEQP and CMLP during the three and six months ended2016.

The following table shows accounts receivable and accounts payable from our affiliates as of June 30, 2016 and December 31, 2015 (in millions):

	CEQP				CMLP
	June 30, 2016		December 31, 2015		June 30, 2016		December 31, 2015
Accounts receivable	$	2.1	$	1.7	$	2.1	$	1.7
Accounts payable	$	6.3	$	4.0	$	3.8	$	1.5

Note 12 – Segments

Financial Information

As discussed in Note 1, on September 30, 2015, the Company contributed 100% of its interest in Crestwood Operations to Crestwood Midstream and as a result, we modified our segments and our financial statements to reflect three operating and reportable segments: (i) gathering and processing operations; (ii) storage and transportation operations; and (iii) marketing, supply and logistics operations (formerly NGL and crude services operations). Consequently, the results of our Arrow operations are now reflected in our gathering and processing operations for all periods presented and our COLT and PRBIC operations are now reflected in our storage and transportation operations for all periods presented. These respective operations were previously included in our NGL and crude services operations. Our corporate operations include all general and administrative expenses that are not allocated to our reportable segments. For a further description of our operating and reporting segments, see Note 1. We assess the performance of our operating segments based on EBITDA, a non-GAAP financial measure, which is defined as income before income taxes, plus debt-related costs (net interest and debt expense and gain or loss on modification/extinguishment of debt) and depreciation, amortization and accretion expense.

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Below is a reconciliation of CEQP's net loss to EBITDA (in millions):

	Three Months Ended						Six Months Ended
	June 30,						June 30,
	2016			2015			2016			2015
Net loss	$	(37.1	)	$	(296.0	)	$	(130.8	)	$	(277.9	)
Add:
Interest and debt expense, net	34.3			35.4			70.4			69.0
(Gain) loss on modification/extinguishment of debt	(10.0		)	17.1			(10.0		)	17.1
Provision (benefit) for income taxes	—			(0.3		)	—			0.1
Depreciation, amortization and accretion	64.4			74.8			126.7			149.0
EBITDA	$	51.6		$	(169.0	)	$	56.3		$	(42.7	)

The following tables summarize CEQP's reportable segment data for the three and six months endedJune 30, 2016 and 2015 (in millions). Included in earnings from unconsolidated affiliates below was approximately $4.4 million and $0.7 million of depreciation and amortization expense and gains (losses) on long-lived assets, net related to our equity investments for the three months endedJune 30, 2016 and 2015 and $7.0 million and $3.8 million for the six months endedJune 30, 2016 and 2015.

	Three Months Ended June 30, 2016
	Gathering and Processing		Storage and Transportation			Marketing, Supply and Logistics			Corporate			Total
Revenues	$	269.5	$	53.8		$	278.6		$	—		$	601.9
Intersegment revenues	30.6		1.1			(31.7		)	—			—
Costs of product/services sold	226.3		1.9			221.8			—			450.0
Operations and maintenance expense	20.9		8.5			15.6			—			45.0
General and administrative expense	—		—			—			28.9			28.9
Loss on long-lived assets	—		(32.7		)	—			—			(32.7		)
Earnings from unconsolidated affiliates, net	5.9		0.3			—			—			6.2
Other income, net	—		—			—			0.1			0.1
EBITDA	$	58.8	$	12.1		$	9.5		$	(28.8	)	$	51.6
Goodwill	$	45.9	$	31.2		$	172.4		$	—		$	249.5
Total assets	$	2,394.1	$	1,191.2		$	974.8		$	33.3		$	4,593.4
Purchases of property, plant and equipment	$	4.2	$	11.6		$	4.7		$	0.1		$	20.6

	Three Months Ended June 30, 2015
	Gathering and Processing			Storage and Transportation		Marketing, Supply and Logistics			Corporate			Total
Revenues	$	346.8		$	68.5	$	226.2		$	—		$	641.5
Intersegment revenues	33.8			—		(33.8		)	—			—
Costs of product/services sold	293.1			5.3		161.1			—			459.5
Operations and maintenance expense	22.3			5.9		15.7			—			43.9
General and administrative expense	—			—		—			30.6			30.6
Loss on long-lived assets	(0.6		)	—		—			—			(0.6		)
Goodwill impairment	(220.7		)	—		(60.3		)	—			(281.0		)
Earnings from unconsolidated affiliates, net	1.1			3.9		—			—			5.0
Other income, net	—			—		—			0.1			0.1
EBITDA	$	(155.0	)	$	61.2	$	(44.7	)	$	(30.5	)	$	(169.0	)
Purchases of property, plant and equipment	$	28.4		$	3.9	$	3.6		$	0.2		$	36.1

33

	Six Months Ended June 30, 2016
	Gathering and Processing			Storage and Transportation			Marketing, Supply and Logistics			Corporate			Total
Revenues	$	508.4		$	113.2		$	516.3		$	—		$	1,137.9
Intersegment revenues	51.1			1.5			(52.6		)	—			—
Costs of product/services sold	406.1			4.8			402.5			—			813.4
Operations and maintenance expense	38.7			15.7			32.4			—			86.8
General and administrative expense	—			—			—			51.9			51.9
Loss on long-lived assets	—			(32.7		)	—			—			(32.7		)
Goodwill impairment	(8.6		)	(13.7		)	(87.4		)	—			(109.7		)
Earnings from unconsolidated affiliates, net	11.0			1.7			—			—			12.7
Other income, net	—			—			—			0.2			0.2
EBITDA	$	117.1		$	49.5		$	(58.6	)	$	(51.7	)	$	56.3
Goodwill	$	45.9		$	31.2		$	172.4		$	—		$	249.5
Total assets	$	2,394.1		$	1,191.2		$	974.8		$	33.3		$	4,593.4
Purchases of property, plant and equipment	$	48.5		$	14.9		$	11.8		$	1.0		$	76.2

	Six Months Ended June 30, 2015
	Gathering and Processing			Storage and Transportation			Marketing, Supply and Logistics			Corporate			Total
Revenues	$	697.1		$	136.1		$	539.8		$	—		$	1,373.0
Intersegment revenues	43.9			—			(43.9		)	—			—
Costs of product/services sold	559.8			10.6			418.8			—			989.2
Operations and maintenance expense	46.4			12.3			35.8			—			94.5
General and administrative expense	—			—			—			58.1			58.1
Goodwill impairment	(220.7		)	—			(60.3		)	—			(281.0		)
Loss on long-lived assets	(0.9		)	(0.7		)	—			—			(1.6		)
Earnings from unconsolidated affiliates, net	3.6			4.8			—			—			8.4
Other income, net	—			—			—			0.3			0.3
EBITDA	$	(83.2	)	$	117.3		$	(19.0	)	$	(57.8	)	$	(42.7	)
Purchases of property, plant and equipment	$	64.6		$	8.0		$	10.5		$	0.4		$	83.5

Below is a reconciliation of CMLP's net loss to EBITDA (in millions):

	Three Months Ended						Six Months Ended
	June 30,						June 30,
	2016			2015			2016			2015
Net loss	$	(35.6	)	$	(72.8	)	$	(130.9	)	$	(43.7	)
Add:
Interest and debt expense, net	34.3			32.6			70.4			62.5
(Gain) loss on modification/extinguishment of debt	(10.0		)	17.1			(10.0		)	17.1
Provision for income taxes	0.2			0.1			—			0.5
Depreciation, amortization and accretion	67.1			69.5			132.0			138.3
EBITDA	$	56.0		$	46.5		$	61.5		$	174.7

The following tables summarize CMLP's reportable segment data for the three and six months endedJune 30, 2016 and 2015 (in millions). Included in earnings from unconsolidated affiliates below was approximately $4.4 million and $0.7 million of

34

depreciation and amortization expense and gains (losses) on long-lived assets, net related to our equity investments for the three months ended June 30, 2016 and 2015 and $7.0 million and $3.8 million for the six months ended June 30, 2016 and 2015.

	Three Months Ended June 30, 2016
	Gathering and Processing		Storage and Transportation			Marketing, Supply and Logistics			Corporate			Total
Revenues	$	269.5	$	53.8		$	278.6		$	—		$	601.9
Intersegment revenues	30.6		1.1			(31.7		)	—			—
Costs of product/services sold	226.3		1.9			221.8			—			450.0
Operations and maintenance expense	20.9		4.9			15.6			—			41.4
General and administrative expense	—		—			—			28.0			28.0
Loss on long-lived assets	—		(32.7		)	—			—			(32.7		)
Earnings from unconsolidated affiliates, net	5.9		0.3			—			—			6.2
EBITDA	$	58.8	$	15.7		$	9.5		$	(28.0	)	$	56.0
Goodwill	$	45.9	$	31.2		$	172.4		$	—		$	249.5
Total assets	$	2,603.3	$	1,188.9		$	974.8		$	18.9		$	4,785.9
Purchases of property, plant and equipment	$	4.2	$	11.6		$	4.7		$	0.1		$	20.6

	Three Months Ended June 30, 2015
	Gathering and Processing			Storage and Transportation			Marketing, Supply and Logistics			Corporate			Total
Revenues	$	346.8		$	68.5		$	226.2		$	—		$	641.5
Intersegment revenues	33.8			—			(33.8		)	—			—
Costs of product/services sold	293.1			5.3			161.1			—			459.5
Operations and maintenance expense	22.3			5.9			15.7			—			43.9
General and administrative expense	—			—			—			27.3			27.3
Goodwill impairment	(8.3		)	—			(60.3		)	—			(68.6		)
Loss on long-lived assets	(0.6		)	(0.1		)	—			—			(0.7		)
Earnings from unconsolidated affiliates, net	1.1			3.9			—			—			5.0
EBITDA	$	57.4		$	61.1		$	(44.7	)	$	(27.3	)	$	46.5
Purchases of property, plant and equipment	$	28.4		$	3.9		$	3.6		$	0.2		$	36.1

	Six Months Ended June 30, 2016
	Gathering and Processing			Storage and Transportation			Marketing, Supply and Logistics			Corporate			Total
Revenues	$	508.4		$	113.2		$	516.3		$	—		$	1,137.9
Intersegment revenues	51.1			1.5			(52.6		)	—			—
Costs of product/services sold	406.1			4.8			402.5			—			813.4
Operations and maintenance expense	38.7			12.0			32.4			—			83.1
General and administrative expense	—			—			—			50.2			50.2
Goodwill impairment	(8.6		)	(13.7		)	(87.4		)	—			(109.7		)
Loss on long-lived assets	—			(32.7		)	—			—			(32.7		)
Earnings from unconsolidated affiliates, net	11.0			1.7			—			—			12.7
EBITDA	$	117.1		$	53.2		$	(58.6	)	$	(50.2	)	$	61.5
Goodwill	$	45.9		$	31.2		$	172.4		$	—		$	249.5
Total assets	$	2,603.3		$	1,188.9		$	974.8		$	18.9		$	4,785.9
Purchases of property, plant and equipment	$	48.5		$	14.9		$	11.8		$	1.0		$	76.2

35

	Six Months Ended June 30, 2015
	Gathering and Processing			Storage and Transportation			Marketing, Supply and Logistics			Corporate			Total
Revenues	$	697.1		$	136.1		$	539.8		$	—		$	1,373.0
Intersegment revenues	43.9			—			(43.9		)	—			—
Costs of product/services sold	559.8			10.6			418.8			—			989.2
Operations and maintenance expense	46.4			12.3			35.8			—			94.5
General and administrative expense	—			—			—			52.9			52.9
Goodwill impairment	(8.3		)	—			(60.3		)	—			(68.6		)
Loss on long-lived assets	(0.9		)	(0.6		)	—			—			(1.5		)
Earnings from unconsolidated affiliates, net	3.6			4.8			—			—			8.4
EBITDA	$	129.2		$	117.4		$	(19.0	)	$	(52.9	)	$	174.7
Purchases of property, plant and equipment	$	64.6		$	8.0		$	10.5		$	0.4		$	83.5

Note 13 – Condensed Consolidating Financial Information

Crestwood Midstream is a holding company (Parent) and owns no operating assets and has no significant operations independent of its subsidiaries. Obligations under Crestwood Midstream's senior notes and its credit facility are jointly and severally guaranteed by substantially all of its subsidiaries, except for Crestwood Delaware Basin LLC, Crestwood Niobrara, Crestwood Northeast, PRBIC and Tres Holdings and their respective subsidiaries (collectively, Non-Guarantor Subsidiaries). Crestwood Midstream Finance Corp., the co-issuer of its senior notes, is Crestwood Midstream's 100% owned subsidiary and has no material assets, operations, revenues or cash flows other than those related to its service as co-issuer of the Crestwood Midstream senior notes.

The tables below present condensed consolidating financial statements for Crestwood Midstream as parent on a stand-alone, unconsolidated basis, and Crestwood Midstream's combined guarantor and combined non-guarantor subsidiaries as of June 30, 2016 and December 31, 2015, and for the three and six months endedJune 30, 2016 and 2015.  The financial information may not necessarily be indicative of the results of operations, cash flows or financial position had the subsidiaries operated as independent entities.

36

Crestwood Midstream Partners LP
Condensed Consolidating Balance Sheet
June 30, 2016
(in millions)
	Parent		Guarantor Subsidiaries		Non- Guarantor Subsidiaries		Eliminations			Consolidated
Assets
Current assets:
Cash	$	0.2	$	—	$	—	$	—		$	0.2
Accounts receivable	—		242.4		1.9		—			244.3
Inventory	—		43.5		—		—			43.5
Assets held for sale	—		55.0		—		—			55.0
Other current assets	—		19.8		—		—			19.8
Total current assets	0.2		360.7		1.9		—			362.8
Property, plant and equipment, net	—		2,355.9		—		—			2,355.9
Goodwill and intangible assets, net	—		965.2		—		—			965.2
Investment in consolidated affiliates	4,310.1		—		—		(4,310.1		)	—
Investment in unconsolidated affiliates	—		—		1,099.1		—			1,099.1
Other assets	—		2.9		—		—			2.9
Total assets	$	4,310.3	$	3,684.7	$	1,101.0	$	(4,310.1	)	$	4,785.9
Liabilities and partners' capital
Current liabilities:
Accounts payable	$	—	$	161.8	$	—	$	—		$	161.8
Other current liabilities	23.4		82.9		—		—			106.3
Total current liabilities	23.4		244.7		—		—			268.1
Long-term liabilities:
Long-term debt, less current portion	1,580.1		1.5		—		—			1,581.6
Other long-term liabilities	—		40.9		—		—			40.9
Deferred income taxes	—		0.7		—		—			0.7
Partners' capital	2,706.8		3,396.9		913.2		(4,310.1		)	2,706.8
Interest of non-controlling partners in subsidiaries	—		—		187.8		—			187.8
Total partners' capital	2,706.8		3,396.9		1,101.0		(4,310.1		)	2,894.6
Total liabilities and partners' capital	$	4,310.3	$	3,684.7	$	1,101.0	$	(4,310.1	)	$	4,785.9

37

Crestwood Midstream Partners LP
Condensed Consolidating Balance Sheet
December 31, 2015
(in millions)
	Parent		Guarantor Subsidiaries		Non- Guarantor Subsidiaries		Eliminations			Consolidated
Assets
Current assets:
Cash	$	0.1	$	—	$	—	$	—		$	0.1
Accounts receivable	—		236.0		0.5		—			236.5
Inventory	—		44.5		—		—			44.5
Other current assets	—		52.5		—		—			52.5
Total current assets	0.1		333.0		0.5		—			333.6
Property, plant and equipment, net	—		3,525.7		—		—			3,525.7
Goodwill and intangible assets, net	—		1,846.9		—		—			1,846.9
Investment in consolidated affiliates	5,506.8		—		—		(5,506.8		)	—
Investment in unconsolidated affiliates	—		—		254.3		—			254.3
Other assets	—		3.1		—		—			3.1
Total assets	$	5,506.9	$	5,708.7	$	254.8	$	(5,506.8	)	$	5,963.6
Liabilities and partners' capital
Current liabilities:
Accounts payable	$	—	$	141.3	$	0.1	$	—		$	141.4
Other current liabilities	26.4		85.2		—		—			111.6
Total current liabilities	26.4		226.5		0.1		—			253.0
Long-term liabilities:
Long-term debt, less current portion	2,498.9		2.9		—		—			2,501.8
Other long-term liabilities	—		43.3		—		—			43.3
Deferred income taxes	—		0.4		—		—			0.4
Partners' capital	2,981.6		5,435.6		71.2		(5,506.8		)	2,981.6
Interest of non-controlling partners in subsidiaries	—		—		183.5		—			183.5
Total partners' capital	2,981.6		5,435.6		254.7		(5,506.8		)	3,165.1
Total liabilities and partners' capital	$	5,506.9	$	5,708.7	$	254.8	$	(5,506.8	)	$	5,963.6

38

Crestwood Midstream Partners LP
Condensed Consolidating Statement of Operations
Three Months Ended June 30, 2016
(in millions)
	Parent			Guarantor Subsidiaries			Non- Guarantor Subsidiaries		Eliminations			Consolidated
Revenues	$	—		$	601.9		$	—	$	—		$	601.9
Costs of product/services sold	—			450.0			—		—			450.0
Expenses:
Operations and maintenance	—			41.4			—		—			41.4
General and administrative	23.2			4.8			—		—			28.0
Depreciation, amortization and accretion	—			67.1			—		—			67.1
	23.2			113.3			—		—			136.5
Other operating expense:
Loss on long-lived assets, net	—			(32.7		)	—		—			(32.7		)
Goodwill impairment	—			—			—		—			—
Operating income (loss)	(23.2		)	5.9			—		—			(17.3		)
Earnings from unconsolidated affiliates, net	—			—			6.2		—			6.2
Interest and debt expense, net	(34.3		)	—			—		—			(34.3		)
Gain on modification/extinguishment of debt	10.0			—			—		—			10.0
Equity in net income (loss) of subsidiary	11.9			—			—		(11.9		)	—
Income (loss) before income taxes	(35.6		)	5.9			6.2		(11.9		)	(35.4		)
Provision for income taxes	—			0.2			—		—			0.2
Net income (loss)	(35.6		)	5.7			6.2		(11.9		)	(35.6		)
Net income attributable to non-controlling partners in subsidiaries	—			—			6.0		—			6.0
Net income (loss) attributable to Crestwood Midstream Partners LP	$	(35.6	)	$	5.7		$	0.2	$	(11.9	)	$	(41.6	)

39

Crestwood Midstream Partners LP
Condensed Consolidating Statement of Operations
Three Months Ended June 30, 2015
(in millions)
	Parent			Guarantor Subsidiaries			Non- Guarantor Subsidiaries			Eliminations		Consolidated
Revenues	$	—		$	641.5		$	—		$	—	$	641.5
Costs of product/services sold	—			459.5			—			—		459.5
Expenses:
Operations and maintenance	—			43.9			—			—		43.9
General and administrative	16.4			10.9			—			—		27.3
Depreciation, amortization and accretion	0.9			68.6			—			—		69.5
	17.3			123.4			—			—		140.7
Other operating expense:
Loss on long-lived assets, net	—			(0.7		)	—			—		(0.7		)
Goodwill Impairment	—			(68.6		)	—			—		(68.6		)
Operating loss	(17.3		)	(10.7		)	—			—		(28.0		)
Earnings from unconsolidated affiliates, net	—			—			5.0			—		5.0
Interest and debt expense, net	(32.6		)	—			—			—		(32.6		)
Loss on modification/extinguishment of debt	(17.1		)	—			—			—		(17.1		)
Equity in net income (loss) of subsidiary	(5.8		)	—			—			5.8		—
Income (loss) before income taxes	(72.8		)	(10.7		)	5.0			5.8		(72.7		)
Provision for income taxes	—			0.1			—			—		0.1
Net income (loss)	(72.8		)	(10.8		)	5.0			5.8		(72.8		)
Net income attributable to non-controlling partners in subsidiaries	—			—			5.7			—		5.7
Net income (loss) attributable to Crestwood Midstream Partners LP	(72.8		)	(10.8		)	(0.7		)	5.8		(78.5		)
Net income attributable to Class A preferred units	7.5			—			—			—		7.5
Net income (loss) attributable to partners	$	(80.3	)	$	(10.8	)	$	(0.7	)	$	5.8	$	(86.0	)

40

Crestwood Midstream Partners LP
Condensed Consolidating Statement of Operations
Six Months Ended June 30, 2016
(in millions)
	Parent			Guarantor Subsidiaries			Non- Guarantor Subsidiaries		Eliminations		Consolidated
Revenues	$	—		$	1,137.9		$	—	$	—	$	1,137.9
Costs of product/services sold	—			813.4			—		—		813.4
Expenses:
Operations and maintenance	—			83.1			—		—		83.1
General and administrative	40.9			9.3			—		—		50.2
Depreciation, amortization and accretion	—			132.0			—		—		132.0
	40.9			224.4			—		—		265.3
Other operating expense:
Loss on long-lived assets, net	—			(32.7		)	—		—		(32.7		)
Goodwill impairment	—			(109.7		)	—		—		(109.7		)
Operating loss	(40.9		)	(42.3		)	—		—		(83.2		)
Earnings from unconsolidated affiliates, net	—			—			12.7		—		12.7
Interest and debt expense, net	(70.4		)	—			—		—		(70.4		)
Gain on modification/extinguishment of debt	10.0			—			—		—		10.0
Equity in net income (loss) of subsidiary	(29.6		)	—			—		29.6		—
Net income (loss)	(130.9		)	(42.3		)	12.7		29.6		(130.9		)
Net income attributable to non-controlling partners in subsidiaries	—			—			11.9		—		11.9
Net income (loss) attributable to Crestwood Midstream Partners LP	$	(130.9	)	$	(42.3	)	$	0.8	$	29.6	$	(142.8	)

41

Crestwood Midstream Partners LP
Condensed Consolidating Statement of Operations
Six Months Ended June 30, 2015
(in millions)
	Parent			Guarantor Subsidiaries			Non- Guarantor Subsidiaries			Eliminations			Consolidated
Revenues	$	—		$	1,373.0		$	—		$	—		$	1,373.0
Costs of product/services sold	—			989.2			—			—			989.2
Expenses:
Operations and maintenance	—			94.5			—			—			94.5
General and administrative	29.8			23.1			—			—			52.9
Depreciation, amortization and accretion	1.1			137.2			—			—			138.3
	30.9			254.8			—			—			285.7
Other operating expense:
Loss on long-lived assets, net	—			(1.5		)	—			—			(1.5		)
Goodwill Impairment	—			(68.6		)	—			—			(68.6		)
Operating income (loss)	(30.9		)	58.9			—			—			28.0
Earnings from unconsolidated affiliates, net	—			—			8.4			—			8.4
Interest and debt expense, net	(62.5		)	—			—			—			(62.5		)
Loss on modification/extinguishment of debt	(17.1		)	—			—			—			(17.1		)
Equity in net income (loss) of subsidiary	66.8			—			—			(66.8		)	—
Income (loss) before income taxes	(43.7		)	58.9			8.4			(66.8		)	(43.2		)
Provision for income taxes	—			0.5			—			—			0.5
Net income (loss)	(43.7		)	58.4			8.4			(66.8		)	(43.7		)
Net income attributable to non-controlling partners in subsidiaries	—			—			11.3			—			11.3
Net income (loss) attributable to Crestwood Midstream Partners LP	(43.7		)	58.4			(2.9		)	(66.8		)	(55.0		)
Net income attributable to Class A preferred units	16.7			—			—			—			16.7
Net income (loss) attributable to partners	$	(60.4	)	$	58.4		$	(2.9	)	$	(66.8	)	$	(71.7	)

42

Crestwood Midstream Partners LP
Condensed Consolidating Statement of Cash Flows
Six Months Ended June 30, 2016
(in millions)
	Parent			Guarantor Subsidiaries			Non- Guarantor Subsidiaries			Eliminations			Consolidated
Cash flows from operating activities:	$	(110.9	)	$	296.5		$	10.4		$	—		$	196.0
Cash flows from investing activities:
Purchases of property, plant and equipment	(1.0		)	(75.2		)	—			—			(76.2		)
Investment in unconsolidated affiliates	—			—			(5.5		)	—			(5.5		)
Proceeds from the sale of assets	—			942.0			—			—			942.0
Capital distributions from unconsolidated affiliates	—			—			5.5			—			5.5
Capital distributions from consolidated affiliates	2.8			—			—			(2.8		)	—
Net cash provided by (used in) investing activities	1.8			866.8			—			(2.8		)	865.8
Cash flows from financing activities:
Proceeds from the issuance of long-term debt	1,078.8			—			—			—			1,078.8
Principal payments on long-term debt	(1,986.8		)	(0.7		)	—			—			(1,987.5		)
Payments on capital leases	—			(0.9		)	—			—			(0.9		)
Payments for debt-related deferred costs	(3.3		)	—			—			—			(3.3		)
Distributions paid	(140.6		)	—			(7.6		)	—			(148.2		)
Distributions to parent	—			—			(2.8		)	2.8			—
Taxes paid for unit-based compensation vesting	—			(0.6		)	—			—			(0.6		)
Change in intercompany balances	1,161.1			(1,161.1		)	—			—			—
Net cash provided by (used in) financing activities	109.2			(1,163.3		)	(10.4		)	2.8			(1,061.7		)
Net change in cash	0.1			—			—			—			0.1
Cash at beginning of period	0.1			—			—			—			0.1
Cash at end of period	$	0.2		$	—		$	—		$	—		$	0.2

43

Crestwood Midstream Partners LP
Condensed Consolidating Statement of Cash Flows
Six Months Ended June 30, 2015
(in millions)
	Parent			Guarantor Subsidiaries			Non- Guarantor Subsidiaries			Eliminations			Consolidated
Cash flows from operating activities:	$	(89.1	)	$	286.6		$	6.0		$	—		$	203.5
Cash flows from investing activities:
Purchases of property, plant and equipment	(0.4		)	(83.1		)	—			—			(83.5		)
Investment in unconsolidated affiliates	—			—			(27.8		)	—			(27.8		)
Capital distributions from unconsolidated affiliates	—			—			1.0			—			1.0
Proceeds from the sale of assets	—			2.1			—			—			2.1
Capital contributions to consolidated affiliates	(24.6		)	—			—			24.6			—
Net cash provided by (used in) investing activities	(25.0		)	(81.0		)	(26.8		)	24.6			(108.2		)
Cash flows from financing activities:
Proceeds from the issuance of long-term debt	1,865.1			—			—			—			1,865.1
Principal payments on long-term debt	(1,713.2		)	—			—			—			(1,713.2		)
Payments on capital leases	(0.9		)	(0.3		)	—			—			(1.2		)
Payments for debt-related deferred costs	(11.7		)	—			—			—			(11.7		)
Financing fees paid for early debt redemption	(13.6		)	—			—			—			(13.6		)
Distributions paid	(221.4		)	—			(3.8		)	—			(225.2		)
Contributions from parent	—			—			24.6			(24.6		)	—
Taxes paid for unit-based compensation vesting	—			(2.1		)	—			—			(2.1		)
Change in intercompany balances	210.0			(210.0		)	—			—			—
Other	(0.2		)	—			—			—			(0.2		)
Net cash provided by (used in) financing activities	114.1			(212.4		)	20.8			(24.6		)	(102.1		)
Net change in cash	—			(6.8		)	—			—			(6.8		)
Cash at beginning of period	—			7.6			—			—			7.6
Cash at end of period	$	—		$	0.8		$	—		$	—		$	0.8

44

Item 2. Management’s Discussion and Analysis of Financial Condition and Results of Operations

Our Management's Discussion and Analysis of Financial Condition and Results of Operations should be read in conjunction with the consolidated financial statements and the accompanying footnotes and Item 7. Management's Discussion and Analysis of Financial Condition and Results of Operations in our 2015 Annual Report on Form 10-K.

This report, including information included or incorporated by reference herein, contains forward-looking statements concerning the financial condition, results of operations, plans, objectives, future performance and business of our company and its subsidiaries. These forward-looking statements include:

• statements that are not historical in nature, including, but not limited to: (i) our belief that anticipated cash from operations, cash distributions from entities that we control, and borrowing capacity under our credit facility will be sufficient to meet our anticipated liquidity needs for the foreseeable future; (ii) our belief that we do not have material potential liability in connection with legal proceedings that would have a significant financial impact on our consolidated financial condition, results of operations or cash flows; and (iii) our belief that our assets will continue to benefit from the development of unconventional shale plays as significant supply basins; and

• statements preceded by, followed by or that contain forward-looking terminology including the words “believe,” “expect,” “may,” “will,” “should,” “could,” “anticipate,” “estimate,” “intend” or the negation thereof, or similar expressions.

Forward-looking statements are not guarantees of future performance or results. They involve risks, uncertainties and assumptions. Actual results may differ materially from those contemplated by the forward-looking statements due to, among others, the following factors:

• our ability to successfully implement our business plan for our assets and operations;

• governmental legislation and regulations;

• industry factors that influence the supply of and demand for crude oil, natural gas and NGLs;

• industry factors that influence the demand for services in the markets (particularly unconventional shale plays) in which we provide services;

• weather conditions;

• the availability of crude oil, natural gas and NGLs, and the price of those commodities, to consumers relative to the price of alternative and competing fuels;

• economic conditions;

• costs or difficulties related to the integration of our existing businesses and acquisitions;

• environmental claims;

• operating hazards and other risks incidental to the provision of midstream services, including gathering, compressing, treating, processing, fractionating, transporting and storing energy products (i.e., crude oil, NGLs and natural gas) and related products (i.e., produced water);

• interest rates;

• the price and availability of debt and equity financing; and

• the ability to sell or monetize assets in the current market, to reduce indebtedness or for other general partnership purposes.

For additional factors that could cause actual results to be materially different from those described in the forward-looking statements, see Part I, Item IA. Risk Factors of our 2015 Annual Report on Form 10-K.

Outlook and Trends

Our business objective is to create long-term value for our stakeholders by maximizing throughput on our assets, expanding our services and exercising prudent control of operating and administrative costs, resulting in stable operating margins and improving cash flows from operations. Our business strategy further depends on our ability to provide increased services to our customers at competitive fees and develop growth projects that can be financed appropriately.

We have positioned the Company to generate consistent results in a low commodity price environment. Many of our assets are located on long-term, core acreage dedications in shale plays which are economic to varying degrees based upon natural gas, NGL and crude oil prices, the availability of midstream infrastructure to flow production to market and the operational and financial condition of our diverse customer base. We believe the diversity of our asset portfolio, wide range of services provided and extensive customer portfolio, taken together, positions us to be successful in the current market, which has been

45

impacted by prolonged low commodity prices. In addition, a substantial portion of the midstream services we provide to customers in the shale plays are based on fixed fee, take-or-pay or cost-of-service agreements that ensure a minimum level of cash flow regardless of actual commodity prices or volumetric throughput. We are actively working with our customers to improve their profitability by adjusting our rates, services and/or volume commitments. Many of the discussions with our customers regarding amendments and/or extensions of their contracts are substantially complete, and we do not expect the results of these discussions to have a significant adverse impact on our 2016 results.

In 2016, we are focused on executing on a strategic plan to substantially de-risk our investment profile. As part of our strategic plan, we recently formed a joint venture with a subsidiary of Con Edison to own and further develop our natural gas storage and transportation operations in the northeast. The proceeds of approximately $945 million received by us in the transaction were used to retire indebtedness (including approximately $623 million of borrowings under Crestwood Midstream's credit facility and approximately $313 million of senior notes), which has substantially reduced our financial leverage and improved our liquidity.

In conjunction with these matters, Crestwood Equity declared a quarterly distribution of $0.60 per common unit for the second quarter of 2016 (or $2.40 per common unit annually), a 56% reduction of the distribution compared to the same period in 2015. This distribution reduction increases our ability to further retire indebtedness to strengthen our balance sheet, and to reinvest capital in our business (including expansions and new growth projects).

During the remainder of 2016, we will continue to execute on our plan to better position the Company to emerge from this challenging market environment as a stronger, better capitalized company. We will remain focused on reducing capital expenditures, eliminating costs (through increased operating efficiencies and otherwise) and exploring options to opportunistically strengthen our balance sheet.

We anticipate that the Company will generate Adjusted EBITDA of $435 million to $465 million in 2016, reflecting our expectations that current industry fundamentals will continue during 2016 and the impact of the contribution of the NE S&T assets to Stagecoach Gas on our 2016 results. We anticipate our gathering and processing segment will generate $235 million to $250 million of EBITDA in 2016, a 10% decrease from 2015, with average volumes being down 15% to 20% year over year driven by our expectation for prolonged weakness in commodity pricing throughout the remainder of 2016. Compared to 2015, we anticipate our gathering and processing volumes in 2016 will be down 10% to 15% for our Barnett operations, 20% to 25% for our Marcellus operations and 1% to 5% for our Arrow operations due to natural declines in production and shut-ins of wells resulting from the continued weakness in commodity pricing in 2016. Our storage and transportation segment is anticipated to generate $170 million to $180 million of EBITDA in 2016, which reflects the impact of the contribution of the NE S&T assets to Stagecoach Gas on our operating results. Finally, we anticipate our marketing, supply and logistics segment will generate $95 million to $100 million of EBITDA in 2016, which is consistent with 2015, with average volumes being flat to 2015. See "How We Evaluate Our Operations" below for our definition of EBITDA and Adjusted EBITDA (non-GAAP measure) and a reconciliation of net income to EBITDA and Adjusted EBITDA.

Through the execution of strategic efforts described above, we expect to increase the stability and strength of the Company through a continued challenging market environment, which will position us to achieve our chief business objective to create long-term value for our stakeholders.

Segment Highlights

Below is a discussion of events that highlight our core business and financing activities.

Gathering and Processing

Barnett Shale. Our gathering and processing systems were integral to Quicksilver Resources, Inc.'s (Quicksilver) Barnett Shale operations, as a substantial amount of Quicksilver's revenues were derived from the sale of natural gas and natural gas liquids produced from acreage dedicated to us. In March 2015, Quicksilver filed for protection under Chapter 11 of the U.S. Bankruptcy Code. In January 2016, Quicksilver executed an asset purchase agreement with BlueStone Natural Resources II, LLC (BlueStone) for the sale of its U.S. oil and gas assets. On April 6, 2016, Quicksilver closed the sale with BlueStone and in connection with the closing, Quicksilver withdrew its motion to reject its gathering agreements with us. In April 2016, we entered into new 10 year agreements with BlueStone to gather and process natural gas across our Alliance, Lake Arlington and Cowtown systems in the Barnett Shale. Under the terms of these agreements, we will gather and process natural gas for BlueStone under fixed-fee and percent-of-proceeds fee structures, and pursuant to the agreements, BlueStone returned wells previously shut-in by Quicksilver to production in July 2016 and will not shut-in or choke back production for economic purposes through the end of 2018. The new agreements with Bluestone are factored into our anticipated 2016 gathering and

46

processing segment results described in Outlook and Trends above, and we believe the agreements will provide further stability to our investment profile.

Delaware Permian. In late 2015, we expanded the Willow Lake processing plant to 50 MMcf/d, which we completed and placed into service in January 2016. The recent expansion of the Willow Lake system was supported by a seven year contract extension with Mewbourne Oil Co. which increased the amount of WolfCamp drilling and rich gas development expected in the area.

Storage and Transportation

In April 2016, Crestwood Northeast and CEGP entered into a definitive agreement to form the Stagecoach JV to own and further develop our NE S&T assets. Pursuant to the contribution agreement, on June 3, 2016, we contributed to Stagecoach Gas the entities owning the NE S&T assets, CEGP contributed $945 million to Stagecoach Gas in exchange for a 50% equity interest in Stagecoach Gas, and Stagecoach Gas distributed to Crestwood Northeast the net cash proceeds received from CEGP. In conjunction with the contribution, we deconsolidated the NE S&T assets on June 3, 2016 and began accounting for our 50% equity interest in Stagecoach Gas under the equity method of accounting. Additional information about the announced joint venture and certain related matters is available on the Form 8-Ks filed by each of Crestwood Equity and Crestwood Midstream on April 22, 2016 and June 8, 2016.

Critical Accounting Estimates

Our critical accounting estimates are consistent with those described in our 2015 Annual Report on Form 10-K. Below is an update of our critical accounting estimates related to goodwill.

Goodwill Impairment

Our goodwill represents the excess of the amount we paid for a business over the fair value of the net identifiable assets acquired. We evaluate goodwill for impairment annually on December 31, and whenever events indicate that it is more likely than not that the fair value of a reporting unit could be less than its carrying amount. This evaluation requires us to compare the fair value of each of our reporting units to its carrying value (including goodwill). If the fair value exceeds the carrying amount, goodwill of the reporting unit is not considered impaired.

We estimate the fair value of our reporting units based on a number of factors, including discount rates, projected cash flows, and the potential value we would receive if we sold the reporting unit. We also compare the total fair value of our reporting units to our overall enterprise value, which considers the market value for our common and preferred units. Estimating projected cash flows requires us to make certain assumptions as it relates to the future operating performance of each of our reporting units (which includes assumptions, among others, about estimating future operating margins and related future growth in those margins, contracting efforts and the cost and timing of facility expansions) and assumptions related to our customers, such as their future capital and operating plans and their financial condition. When considering operating performance, various factors are considered such as current and changing economic conditions and the commodity price environment, among others. Due to the imprecise nature of these projections and assumptions, actual results can and often do, differ from our estimates. If the assumptions embodied in the projections prove inaccurate, we could incur a future impairment charge. In addition, the use of the income approach to determine the fair value of our reporting units (see further discussion of the use of the income approach below) could result in a different fair value if we had utilized a market approach, or a combination thereof.

We acquired substantially all of our reporting units in 2013, 2012 and 2011, which required us to record the assets, liabilities and goodwill of each of those reporting units at fair value on the date they were acquired. As a result, any level of decrease in the forecasted cash flows of these businesses or increases in the discount rates utilized to value those businesses from their respective acquisition dates would likely result in the fair value of the reporting unit falling below the carrying value of the reporting unit, and could result in an assessment of whether that reporting unit's goodwill is impaired.

Commodity prices have continued to decline since late 2014, and that decline has adversely impacted forecasted cash flows, discount rates and stock/unit prices for most companies in the midstream industry, including us. In particular, due to the significant, sustained decrease in the market price of our common units during the first quarter of 2016, we evaluated the carrying value of our reporting units and determined it was more likely than not that the goodwill associated with several of our reporting units was impaired as of March 31, 2016. As a result of further analysis of the fair value of our reporting units, we recorded goodwill impairments on several of our reporting units during the first quarter of 2016. We did not record any goodwill impairments during the three months ended June 30, 2016.

47

The following table summarizes the goodwill of our various reporting units (in millions):

	Goodwill at		Goodwill Impairments during the  Six Months Ended		Deconsolidation of the NE S&T Assets at		Goodwill at
	December 31, 2015		June 30, 2016		June 30, 2016		June 30, 2016
Gathering and Processing
Marcellus	$	8.6	$	8.6	$	—	$	—
Arrow	45.9		—		—		45.9
Storage and Transportation
Northeast Storage and Transportation	726.3		—		726.3		—
COLT	44.9		13.7		—		31.2
Marketing, Supply and Logistics					—
Supply and Logistics	167.2		65.5		—		101.7
Storage and Terminals	50.5		14.1		—		36.4
US Salt	12.6		—		—		12.6
Trucking	29.5		7.8		—		21.7
Total	$	1,085.5	$	109.7	$	726.3	$	249.5

The goodwill impairments recorded during the first quarter of 2016 primarily resulted from increasing the discount rates utilized in determining the fair value of the reporting units for certain of those reporting units considering the significant, sustained decrease in the market price of our common units and the continued decrease in commodity prices and its impact on the midstream industry and our customers. We utilized the income approach to determine the fair value of our reporting units given the limited availability of comparable market-based transactions as of March 31, 2016 and December 31, 2015, and we utilized discount rates ranging from 10% to 19% in applying the income approach to determine the fair value of our reporting units with goodwill as of March 31, 2016. Our COLT, Supply and Logistics, Storage and Terminals and Trucking reporting units also experienced impairments during 2015 based on the impact that the prolonged low commodity price environment is expected to have on the demand for future services provided by these operations. Despite increases in the operating results of these reporting units from 2013 to 2015, in light of our modified expectations, we revised our cash flow forecasts for these operations at December 31, 2015 in light of our current view that these operations will not grow as fast or as significantly in the future as originally forecasted in 2013 when the assets were acquired.

We continue to monitor the remaining goodwill described in the table above, and we could experience additional impairments of the remaining goodwill in the future if we experience a significant sustained decrease in the market value of our common or preferred units or if we receive additional negative information about market conditions or the intent of our customers on our remaining operations with goodwill, which could negatively impact the forecasted cash flows or discount rates utilized to determine the fair value of those businesses. In particular, a 5% decrease in the forecasted cash flows or a 1% increase in the discount rates utilized to determine the fair value of our businesses that recorded goodwill impairments in 2016 could have resulted in an additional $35 million of goodwill impairments as of March 31, 2016. There we no triggers which required us to evaluate our goodwill for impairment during the three months ended June 30, 2016.

How We Evaluate Our Operations

We evaluate our overall business performance based primarily on EBITDA and Adjusted EBITDA. We evaluate our ability to make distributions to our unitholders based on cash available for distribution and distributions received from Crestwood Midstream.

We do not utilize depreciation, depletion and amortization expense in our key measures because we focus our performance management on cash flow generation and our assets have long useful lives.

EBITDA and Adjusted EBITDA - We believe that EBITDA and Adjusted EBITDA are widely accepted financial indicators of a company's operational performance and its ability to incur and service debt, fund capital expenditures and make distributions. We believe that EBITDA and Adjusted EBITDA are useful to our investors because it allows them to use the same performance measure analyzed internally by our management to evaluate the performance of our businesses and investments without regard

48

to the manner in which they are financed or our capital structure. EBITDA is defined as income before income taxes, plus debt-related costs (net interest and debt expense and gain or loss on modification/extinguishment of debt) and depreciation, amortization and accretion expense. In addition, Adjusted EBITDA considers the adjusted earnings impact of our unconsolidated affiliates by adjusting our equity earnings or losses from our unconsolidated affiliates to reflect our proportionate share (based on the distribution percentage) of their EBITDA, excluding impairments. Adjusted EBITDA also considers the impact of certain significant items, such as unit-based compensation charges, losses on long-lived assets, impairments of goodwill, third party costs incurred related to potential and completed acquisitions, certain environmental remediation costs, certain costs related to our 2015 cost savings initiatives, the change in fair value of commodity inventory-related derivative contracts, and other transactions identified in a specific reporting period. The change in fair value of commodity inventory-related derivative contracts is considered in determining Adjusted EBITDA given that the timing of recognizing gains and losses on these derivative contracts differs from the recognition of revenue for the related underlying sale of inventory that these derivatives relate to. Changes in the fair value of other derivative contracts is not considered in determining Adjusted EBITDA given the relatively short-term nature of those derivative contracts. EBITDA and Adjusted EBITDA are not measures calculated in accordance with GAAP, as they do not include deductions for items such as depreciation, amortization and accretion, interest and income taxes, which are necessary to maintain our business. EBITDA and Adjusted EBITDA should not be considered an alternative to net income, operating cash flow or any other measure of financial performance presented in accordance with GAAP. EBITDA and Adjusted EBITDA calculations may vary among entities, so our computation may not be comparable to measures used by other companies.

See our reconciliation of net income to EBITDA and Adjusted EBITDA in Results of Operations below.

49

Results of Operations

In conjunction with the closing of the Simplification Merger on September 30, 2015, CEQP contributed 100% of its interest in Crestwood Operations to CMLP, and as a result of this equity contribution, CMLP controls the operating and financial decisions of Crestwood Operations. CMLP accounted for this transaction as a reorganization of entities under common control and the accounting standards related to such transactions requires CMLP to retroactively adjust its historical results to reflect the operations of Crestwood Operations as being acquired on June 19, 2013, the date in which CMLP and Crestwood Operations came under common control. The contribution of Crestwood Operations to CMLP had no impact on CEQP's results of operations.

The following tables summarize our results of operations for the three and six months endedJune 30, 2016 and 2015 (in millions):

	Crestwood Equity												Crestwood Midstream
	Three Months Ended						Six Months Ended						Three Months Ended						Six Months Ended
	June 30,						June 30,						June 30,						June 30,
	2016			2015			2016			2015			2016			2015			2016			2015
Revenues	$	601.9		$	641.5		$	1,137.9		$	1,373.0		$	601.9		$	641.5		$	1,137.9		$	1,373.0
Costs of product/services sold	450.0			459.5			813.4			989.2			450.0			459.5			813.4			989.2
Operations and maintenance expense	45.0			43.9			86.8			94.5			41.4			43.9			83.1			94.5
General and administrative expense	28.9			30.6			51.9			58.1			28.0			27.3			50.2			52.9
Depreciation, amortization and accretion	64.4			74.8			126.7			149.0			67.1			69.5			132.0			138.3
Loss on long-lived assets, net	(32.7		)	(0.6		)	(32.7		)	(1.6		)	(32.7		)	(0.7		)	(32.7		)	(1.5		)
Goodwill impairment	—			(281.0		)	(109.7		)	(281.0		)	—			(68.6		)	(109.7		)	(68.6		)
Operating income (loss)	(19.1		)	(248.9		)	(83.3		)	(200.4		)	(17.3		)	(28.0		)	(83.2		)	28.0
Earnings from unconsolidated affiliates, net	6.2			5.0			12.7			8.4			6.2			5.0			12.7			8.4
Interest and debt expense, net	(34.3		)	(35.4		)	(70.4		)	(69.0		)	(34.3		)	(32.6		)	(70.4		)	(62.5		)
Gain (loss) on modification/extinguishment of debt	10.0			(17.1		)	10.0			(17.1		)	10.0			(17.1		)	10.0			(17.1		)
Other income, net	0.1			0.1			0.2			0.3			—			—			—			—
(Provision) benefit for income taxes	—			0.3			—			(0.1		)	(0.2		)	(0.1		)	—			(0.5		)
Net loss	(37.1		)	(296.0		)	(130.8		)	(277.9		)	(35.6		)	(72.8		)	(130.9		)	(43.7		)
Add:
Interest and debt expense, net	34.3			35.4			70.4			69.0			34.3			32.6			70.4			62.5
(Gain) loss on modification/extinguishment of debt	(10.0		)	17.1			(10.0		)	17.1			(10.0		)	17.1			(10.0		)	17.1
Provision (benefit) for income taxes	—			(0.3		)	—			0.1			0.2			0.1			—			0.5
Depreciation, amortization and accretion	64.4			74.8			126.7			149.0			67.1			69.5			132.0			138.3
EBITDA	51.6			(169.0		)	56.3			(42.7		)	56.0			46.5			61.5			174.7
Unit-based compensation charges	4.8			5.9			9.3			11.7			4.8			5.3			9.3			10.5
Loss on long-lived assets, net	32.7			0.6			32.7			1.6			32.7			0.7			32.7			1.5
Goodwill impairment	—			281.0			109.7			281.0			—			68.6			109.7			68.6
Earnings from unconsolidated affiliates, net	(6.2		)	(5.0		)	(12.7		)	(8.4		)	(6.2		)	(5.0		)	(12.7		)	(8.4		)
Adjusted EBITDA from unconsolidated affiliates, net	10.6			5.7			19.7			12.2			10.6			5.7			19.7			12.2
Change in fair value of commodity inventory-related derivative contracts	3.5			1.5			0.8			2.6			3.5			1.5			0.8			2.6
Significant transaction and environmental related costs and other items	9.5			12.4			10.7			17.0			9.5			10.4			10.7			14.2
Adjusted EBITDA	$	106.5		$	133.1		$	226.5		$	275.0		$	110.9		$	133.7		$	231.7		$	275.9

50

	Crestwood Equity												Crestwood Midstream
	Three Months Ended						Six Months Ended						Three Months Ended						Six Months Ended
	June 30,						June 30,						June 30,						June 30,
	2016			2015			2016			2015			2016			2015			2016			2015
Net cash provided by operating activities	$	58.7		$	54.5		$	193.0		$	211.1		$	60.3		$	97.8		$	196.0		$	203.5
Net changes in operating assets and liabilities	(2.7		)	31.6			(53.3		)	(28.0		)	0.4			(5.7		)	(50.3		)	(8.9		)
Amortization of debt-related deferred costs, discounts and premiums	(1.7		)	(2.3		)	(3.4		)	(4.4		)	(1.7		)	(2.0		)	(3.4		)	(3.9		)
Interest and debt expense, net	34.3			35.4			70.4			69.0			34.3			32.6			70.4			62.5
Market adjustment on interest rate swaps	—			0.2			—			0.5			—			—			—			—
Unit-based compensation charges	(4.8		)	(5.9		)	(9.3		)	(11.7		)	(4.8		)	(5.3		)	(9.3		)	(10.5		)
Loss on long-lived assets, net	(32.7		)	(0.6		)	(32.7		)	(1.6		)	(32.7		)	(0.7		)	(32.7		)	(1.5		)
Goodwill impairment	—			(281.0		)	(109.7		)	(281.0		)	—			(68.6		)	(109.7		)	(68.6		)
Earnings (loss) from unconsolidated affiliates, net, adjusted for cash distributions	—			(1.3		)	0.8			2.1			—			(1.3		)	0.8			2.1
Deferred income taxes	0.5			0.7			0.6			1.6			—			(0.2		)	(0.2		)	(0.3		)
Provision (benefit) for income taxes	—			(0.3		)	—			0.1			0.2			0.1			—			0.5
Other non-cash income	—			—			(0.1		)	(0.4		)	—			(0.2		)	(0.1		)	(0.2		)
EBITDA	51.6			(169.0		)	56.3			(42.7		)	56.0			46.5			61.5			174.7
Unit-based compensation charges	4.8			5.9			9.3			11.7			4.8			5.3			9.3			10.5
Loss on long-lived assets, net	32.7			0.6			32.7			1.6			32.7			0.7			32.7			1.5
Goodwill impairment	—			281.0			109.7			281.0			—			68.6			109.7			68.6
Earnings from unconsolidated affiliates, net	(6.2		)	(5.0		)	(12.7		)	(8.4		)	(6.2		)	(5.0		)	(12.7		)	(8.4		)
Adjusted EBITDA from unconsolidated affiliates, net	10.6			5.7			19.7			12.2			10.6			5.7			19.7			12.2
Change in fair value of commodity inventory-related derivative contracts	3.5			1.5			0.8			2.6			3.5			1.5			0.8			2.6
Significant transaction and environmental related costs and other items	9.5			12.4			10.7			17.0			9.5			10.4			10.7			14.2
Adjusted EBITDA	$	106.5		$	133.1		$	226.5		$	275.0		$	110.9		$	133.7		$	231.7		$	275.9

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Segment Results

In conjunction with the Simplification Merger, we modified our business segments and our financial statements to reflect three operating and reporting segments: (i) gathering and processing (G&P); (ii) storage and transportation; and (iii) marketing, supply and logistics (formerly NGL and crude services operations). Consequently, the results of our Arrow operations are now reflected in our gathering and processing operations for all periods presented and our COLT and PRBIC operations are now reflected in our storage and transportation operations for all periods presented. These respective operations were previously included in our NGL and crude services operations.

The following tables summarize the EBITDA of our segments (in millions):

Crestwood Equity

	Three Months Ended								Three Months Ended
	June 30, 2016								June 30, 2015
	Gathering and Processing		Storage and Transportation			Marketing, Supply and Logistics			Gathering and Processing			Storage and Transportation		Marketing, Supply and Logistics
Revenues	$	269.5	$	53.8		$	278.6		$	346.8		$	68.5	$	226.2
Intersegment revenues	30.6		1.1			(31.7		)	33.8			—		(33.8		)
Costs of product/services sold	226.3		1.9			221.8			293.1			5.3		161.1
Operations and maintenance expense	20.9		8.5			15.6			22.3			5.9		15.7
Goodwill impairment	—		—			—			(220.7		)	—		(60.3		)
Loss on long-lived assets	—		(32.7		)	—			(0.6		)	—		—
Earnings from unconsolidated affiliates, net	5.9		0.3			—			1.1			3.9		—
EBITDA	$	58.8	$	12.1		$	9.5		$	(155.0	)	$	61.2	$	(44.7	)

	Six Months Ended									Six Months Ended
	June 30, 2016									June 30, 2015
	Gathering and Processing			Storage and Transportation			Marketing, Supply and Logistics			Gathering and Processing			Storage and Transportation			Marketing, Supply and Logistics
Revenues	$	508.4		$	113.2		$	516.3		$	697.1		$	136.1		$	539.8
Intersegment revenues	51.1			1.5			(52.6		)	43.9			—			(43.9		)
Costs of product/services sold	406.1			4.8			402.5			559.8			10.6			418.8
Operations and maintenance expense	38.7			15.7			32.4			46.4			12.3			35.8
Goodwill impairment	(8.6		)	(13.7		)	(87.4		)	(220.7		)	—			(60.3		)
Loss on long-lived assets	—			(32.7		)	—			(0.9		)	(0.7		)	—
Earnings from unconsolidated affiliates, net	11.0			1.7			—			3.6			4.8			—
EBITDA	$	117.1		$	49.5		$	(58.6	)	$	(83.2	)	$	117.3		$	(19.0	)

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Crestwood Midstream

	Three Months Ended								Three Months Ended
	June 30, 2016								June 30, 2015
	Gathering and Processing		Storage and Transportation			Marketing, Supply and Logistics			Gathering and Processing			Storage and Transportation			Marketing, Supply and Logistics
Revenues	$	269.5	$	53.8		$	278.6		$	346.8		$	68.5		$	226.2
Intersegment revenues	30.6		1.1			(31.7		)	33.8			—			(33.8		)
Costs of product/services sold	226.3		1.9			221.8			293.1			5.3			161.1
Operations and maintenance expense	20.9		4.9			15.6			22.3			5.9			15.7
Goodwill impairment	—		—			—			(8.3		)	—			(60.3		)
Loss on long-lived assets	—		(32.7		)	—			(0.6		)	(0.1		)	—
Earnings from unconsolidated affiliates, net	5.9		0.3			—			1.1			3.9			—
EBITDA	$	58.8	$	15.7		$	9.5		$	57.4		$	61.1		$	(44.7	)

	Six Months Ended									Six Months Ended
	June 30, 2016									June 30, 2015
	Gathering and Processing			Storage and Transportation			Marketing, Supply and Logistics			Gathering and Processing			Storage and Transportation			Marketing, Supply and Logistics
Revenues	$	508.4		$	113.2		$	516.3		$	697.1		$	136.1		$	539.8
Intersegment revenues	51.1			1.5			(52.6		)	43.9			—			(43.9		)
Costs of product/services sold	406.1			4.8			402.5			559.8			10.6			418.8
Operations and maintenance expense	38.7			12.0			32.4			46.4			12.3			35.8
Goodwill impairment	(8.6		)	(13.7		)	(87.4		)	(8.3		)	—			(60.3		)
Loss on long-lived assets	—			(32.7		)	—			(0.9		)	(0.6		)	—
Earnings from unconsolidated affiliates, net	11.0			1.7			—			3.6			4.8			—
EBITDA	$	117.1		$	53.2		$	(58.6	)	$	129.2		$	117.4		$	(19.0	)

53

Below is a discussion of the factors that impacted EBITDA by segment for the three and six months ended June 30, 2016 compared to the same periods in 2015.

Gathering and Processing

EBITDA for CMLP's G&P segment increased by approximately $1.4 million for the three months ended June 30, 2016 compared to the same period in 2015, while we experienced a decrease in CMLP's G&P segment EBITDA of approximately $12.1 million for the six months ended June 30, 2016 compared to the same period in 2015. The comparability of our G&P segment's results period over period is impacted by goodwill impairments recorded during the first quarter of 2016 and the second quarter of 2015, which are further described below. In addition, during the three and six months ended June 30, 2016, our G&P segment's revenues were lower by approximately $80.5 million and $181.5 million compared to the same periods in 2015, partially offset by lower costs of product/services sold of approximately $66.8 million and $153.7 million. These decreases were primarily driven by our Arrow operations, which experienced a $66.2 million and $151.7 million reduction in revenues, substantially offset by a $65.9 million and $150.3 million decrease in costs of products/services sold. The decrease in Arrow's product revenues and costs of product/services sold was driven by reduced market prices on crude oil, which caused average crude oil prices on our sales to decrease during the three and six months ended June 30, 2016 compared to the same periods in 2015.

Also contributing to the decrease in our G&P segment's revenues were lower service revenues from our Marcellus and Barnett operations of approximately $7.6 million and $6.7 million, respectively, during the three months ended June 30, 2016 compared to the same period in 2015 and $15.2 million and $12.8 million, respectively, during the six months ended June 30, 2016 compared to the same period in 2015. During the three and six months ended June 30, 2016, we experienced a decrease in our gathering and compression volumes on our Marcellus system due to lack of drilling from our primary customer, Antero Resources Appalachian Corporation, as a result of the decline in commodity prices. During the three and six months ended June 30, 2016, our gathering and compression volumes on our Marcellus system were 0.4 Bcf/d and 0.5 Bcf/d, respectively, compared to 0.6 Bcf/d and 0.7 Bcf/d, respectively, during the same periods in 2015. The service revenues from our Barnett operations decreased by $6.9 million during the second quarter of 2015 compared to the same period in 2014, and decreased by another $6.7 million during the second quarter of 2016 compared to the same period in 2015 as a result of our primary customer in the Barnett, Quicksilver, ceasing drilling and shutting in production in 2015 and the first quarter of 2016 as a result of its filing for protection under Chapter 11 of the U.S. Bankruptcy Code in 2015 (see "Segment Highlights" above for an update on the Quicksilver Bankruptcy). Our new customer in the Barnett, BlueStone, brought the shut-in wells back online throughout the second quarter of 2016, such that by June 30, 2016 substantially all wells previously shut-in by Quicksilver had resumed flowing volumes. Partially offsetting the decrease in revenues from our Arrow, Marcellus and Barnett operations was a $1.4 million and $7.7 million decrease in operations and maintenance expenses during the three and six months ended June 30, 2016 compared to the same periods in 2015 that resulted from our cost-savings initiative implemented in 2015.

Our G&P segment's EBITDA was also impacted by an $8.6 million impairment of goodwill associated with our Marcellus system during the three months ended March 31, 2016 and an $8.3 million impairment of goodwill associated with our Fayetteville system during the three months ended June 30, 2015. For a further discussion of our goodwill impairments recorded during 2016 and 2015, see "Critical Accounting Estimates" above and Item I. Financial Statements, Note 2.

During the three and six months ended June 30, 2016, our equity earnings from our Jackalope investment increased by approximately $4.8 million and $7.4 million primarily due to higher gathering and processing volumes at the facility resulting from Jackalope placing the Bucking Horse processing plant into service in 2015.

EBITDA for CEQP's G&P segment increased by $213.8 million and $200.3 million for the three and six months ended June 30, 2016 compared to the same periods in 2015 due to all the factors as discussed above for CMLP. In addition to the goodwill impairments described above for the six months ended June 30, 2015, CEQP's G&P segment was also impacted by a $212.4 million goodwill impairment on our Barnett assets due to the impact of Quicksilver's filing for protection under Chapter 11 of the U.S. Bankruptcy Code in 2015 and the impact of the decrease in commodity prices on discount rates. For a further discussion of our goodwill impairments recorded during 2015, see and Item I. Financial Statements, Note 2.

Storage and Transportation

EBITDA for CMLP's storage and transportation segment decreased by approximately $45.4 million and $64.2 million for the three and six months ended June 30, 2016 compared to the same periods in 2015, primarily due to a $32.9 million loss recognized on the deconsolidation of our NE S&T assets as a result of the contribution of the assets to Stagecoach Gas on June 3, 2016. The deconsolidation of the NE S&T assets resulted in lower revenues of approximately $14.0 million and $16.4 million during the three and six months ended June 30, 2016, partially offset by lower costs of product/services sold of

54

approximately $1.7 million and $2.1 million. We also experienced lower operations and maintenance expense of approximately $1.0 million and $0.3 million during the three and six months ended June 30, 2016 compared to the same periods in 2015 primarily as a result of the deconsolidation of the NE S&T assets. See Item 1. Financial Statements, Notes 2 and 4 for a further discussion of the deconsolidation of our NE S&T assets.

Also contributing to the decrease in our storage and transportation segment's EBITDA were lower revenues of approximately $5.0 million, partially offset by lower costs of product/services sold of $3.6 million during the six months ended June 30, 2016 compared to the same period in 2015. This net decrease primarily resulted from lower rail loading volumes at our COLT Hub that resulted from narrowed crude oil locational differences during the quarter and two rail loading contracts that expired in late 2015.

Our storage and transportation segment's EBITDA for the six months ended June 30, 2016 was also impacted by a $13.7 million goodwill impairment related to our COLT Hub operations. For a further discussion of our goodwill impairments recorded during 2016, see "Critical Accounting Estimates" above and Item I. Financial Statements, Note 2.

As discussed above, effective June 3, 2016, we deconsolidated the NE S&T assets as a result of this transaction and began accounting for our 50% equity interest in Stagecoach Gas under the equity method of accounting. We recognized equity earnings from Stagecoach Gas of approximately $2.3 million during the three and six months ended June 30, 2016. Our equity earnings from Tres Holdings were lower by approximately $3 million during the three and six months ended June 30, 2016 compared to the same periods in 2015, primarily due to an increase in property tax accruals at the equity investment. For both the three and six months ended June 30, 2015, our proportionate share of the net earnings from our unconsolidated affiliate, PRBIC, was $3.3 million compared to $0.3 million and $0.9 million during the three and six months ended June 30, 2016. For additional information on our investments in unconsolidated affiliates, see Item 1. Financial Statements, Note 4.

EBITDA for CEQP's storage and transportation segment decreased by $49.1 million and $67.8 million for the three and six months ended June 30, 2016 compared to the same periods in 2015 due to all the factors as discussed above for CMLP. In addition, in June 2016, the Matagorda County court issued a final judgment related to Tres Palacios' 2012 and 2013 property tax years which resulted in Crestwood Equity recording additional net property taxes (including interest and penalties) of approximately $3.5 million. See Item 1. Financial Statements, Note 10 for a further discussion of CEQP's property tax matters.

Marketing, Supply and Logistics

EBITDA for our marketing, supply and logistics segment increased by approximately $54.2 million for the three months ended June 30, 2016 compared to the same period in 2015, while we experienced a decrease in our marketing, supply and logistics segment's EBITDA of approximately $39.6 million during the six months ended June 30, 2016 compared to the same period in 2015. The comparability of our marketing, supply and logistics segment's results period over period is impacted by goodwill impairments recorded during the first quarter of 2016 and the second quarter of 2015, which are further described below.

Our NGL and crude trucking operations experienced a continued decrease in the demand for their services due to lower volumes, increased competition and excess trucking capacity in the market place and the low commodity price environment during the six months ended June 30, 2016, resulting in a 27% and 58% decrease in NGL and crude volumes transported, respectively, a $19.3 million decrease in revenues and a $12.3 million decrease in costs of services sold from these operations during the six months ended June 30, 2016 when compared to the same period in 2015. Our other NGL terminalling, supply and logistics operations experienced an $80.6 million decrease in revenues and a $78.2 million decrease in costs of product/services sold when compared to the same period in 2015 due to the low commodity price environment coupled with warmer weather during 2016 compared to 2015. These revenue and costs of services decreases related to our NGL terminalling, supply and logistics operations include a gain on our commodity-based derivative contracts of approximately $2.0 million and $5.3 million during the six months ended June 30, 2016 and 2015.

During the three and six months ended June 30, 2016, revenues from our crude marketing operations increased by approximately $51.3 million and $64.5 million compared to the same periods in 2015, in addition to an increase of approximately $50.9 million and $64.3 million in our costs of product/services sold period over period. These increases were driven by higher crude marketing volumes, partially offset by lower commodity prices.

Our marketing, supply and logistics segment's operations and maintenance expense decreased by $3.4 million during the six months ended June 30, 2016 compared to the same period in 2015, primarily due to our cost-savings initiative implemented in 2015. Our operations and maintenance expense was relatively flat for the three months ended June 30, 2016 compared to the same period in 2015.

55

Our marketing, supply and logistics segment's EBITDA for the six months ended June 30, 2016 was also impacted by an $87.4 million impairment of goodwill associated with our supply and logistics, storage and terminals and trucking operations. During both the three and six months ended June 30, 2015, we recorded a $28.4 million and a $31.9 million impairment of goodwill associated with our West Coast operations and our Watkins Glen operations, respectively. For a further discussion of our goodwill impairments recorded during 2016 and 2015, see "Critical Accounting Estimates" above and Item I. Financial Statements, Note 2.

Other EBITDA Results

General and Administrative Expenses. As discussed in Item 1. Financial Statements, Note 12, our corporate operations include all general and administrative expenses that are not allocated to our reporting segments, however such expenses impact our consolidated EBITDA.

Crestwood Equity's general and administrative expenses decreased by approximately $1.7 million and $6.2 million during the three and six months ended June 30, 2016 compared to the same periods in 2015 primarily due to the cost-savings initiative implemented in 2015. Crestwood Midstream's general and administrative expenses increased by approximately $0.7 million during the three months ended June 30, 2016 compared to the same period in 2015, while decreasing by approximately $2.7 million during the six months ended June 30, 2016 compared to the same period in 2015. The period over period variance in Crestwood Midstream's general and administrative expenses were primarily driven by transaction costs related to the Stagecoach Gas transaction, offset by lower costs associated with the cost-savings initiative implemented in 2015.

Net Income (Loss) Attributable to Non-Controlling Partners. The decrease in Crestwood Equity's net loss attributable to non-controlling partners was due primarily to Crestwood Midstream becoming a wholly-owned subsidiary of Crestwood Equity as a result of the Simplification Merger on September 30, 2015. See Item 1. Financial Statements, Note 9 for further detail of Crestwood Equity's net income (loss) attributable to non-controlling partners.

Items not affecting EBITDA include the following:

Depreciation, Amortization and Accretion Expense - During the three and six months ended June 30, 2016, our depreciation, amortization and accretion expense decreased compared to the same period in 2015, primarily due to a reduction in the carrying value of certain of our assets as a result of impairments of our property, plant and equipment and intangible assets recorded during 2015 and the deconsolidation of our NE S&T assets on June 3, 2016.

Interest and Debt Expense, Net - Crestwood Midstream's interest and debt expense, net increased by approximately $1.7 million and $7.9 million during the three and six months ended June 30, 2016 compared to the same periods in 2015, primarily due to the issuance of its 2023 Senior Notes in March 2015 and higher outstanding balances on its credit facility. Crestwood Equity's interest and debt expense, net decreased by approximately $1.1 million during the three months ended June 30, 2016 compared to the same period in 2015 primarily due to repayment of its senior notes in 2015. During the six months ended June 30, 2016, Crestwood Equity's interest and debt expense, net increased by approximately $1.4 million during the compared to the same period in 2015, due to the factors discussed above for Crestwood Midstream.

The following table provides a summary of interest and debt expense (in millions):

	Crestwood Equity								Crestwood Midstream
	Three Months Ended				Six Months Ended				Three Months Ended				Six Months Ended
	June 30,				June 30,				June 30,				June 30,
	2016		2015		2016		2015		2016		2015		2016		2015
Credit facilities	$	6.1	$	5.6	$	13.1	$	12.9	$	6.1	$	3.1	$	13.1	$	7.4
Senior notes	26.6		28.4		54.3		53.0		26.6		28.2		54.3		52.6
Other debt-related costs	1.8		2.3		3.5		4.7		1.8		2.2		3.5		4.1
Gross interest and debt expense	34.5		36.3		70.9		70.6		34.5		33.5		70.9		64.1
Less: capitalized interest	0.2		0.9		0.5		1.6		0.2		0.9		0.5		1.6
Interest and debt expense, net	$	34.3	$	35.4	$	70.4	$	69.0	$	34.3	$	32.6	$	70.4	$	62.5

56

Gain (Loss) on Modification/Extinguishment of Debt. During the three and six months ended June 30, 2016, we recognized a gain on extinguishment of debt of approximately $10.0 million in conjunction with the early tender of a portion of our 2020 Senior Notes and 2022 Senior Notes.

During the three and six months ended June 30, 2015, we recognized a loss on modification/extinguishment of debt of approximately $17.1 million related to the redemption of Crestwood Midstream's 2019 Senior Notes.

Liquidity and Sources of Capital

Crestwood Equity is a holding company that derives all of its operating cash flow from its operating subsidiaries.  Our principal sources of liquidity include cash generated by operating activities from our subsidiaries and distributions from our joint venture investments, credit facilities, debt issuances, and sales of common and preferred units. Our operating subsidiaries use cash from their respective operations to fund their operating activities, maintenance and growth capital expenditures, and service their outstanding indebtedness. We believe our liquidity sources and operating cash flows are sufficient to address our future operating, debt service and capital requirements.

As described in Outlook and Trends above, we completed the formation of a joint venture with a subsidiary of Con Edison to own and further develop our natural gas storage and transportation operations in the northeast. The contribution of the NE S&T assets to Stagecoach Gas resulted in a distribution to us of approximately $945 million during the second quarter of 2016, which was utilized to retire indebtedness (including a portion of the principal amounts outstanding under our 2020 Senior Notes and 2022 Senior Notes and borrowings under Crestwood Midstream's credit facility). This substantially reduced our financial leverage and improved our liquidity. In conjunction with these matters, Crestwood Equity declared a quarterly distribution of $0.60 per common unit for the second quarter of 2016 (or $2.40 per common unit annually), a 56% reduction of the distribution compared to the same period in 2015. This distribution reduction increases our ability to further retire indebtedness to strengthen our balance sheet, and to reinvest capital in our business (including expansions and new growth projects). We believe that the reduction of our indebtedness and reduction of our distributions will provide us with ample liquidity to address our future operating, debt service and capital requirements without accessing the capital markets in the near future. We also believe that our operating cash flows will well exceed our quarterly distributions at the current reduced level throughout 2016.

As of June 30, 2016, Crestwood Midstream had $613.9 million of available capacity under its credit facility considering the most restrictive debt covenants in its credit agreement. As further described in Item 1. Financial Statements, Note 7, Crestwood Midstream amended its credit facility during the second quarter of 2016 to, among other things, facilitate the announced joint venture with Con Edison and retire indebtedness with the proceeds thereof. Additional information about the amendment is available on the Form 8-K filed by each of Crestwood Equity and Crestwood Midstream on April 22, 2016 and June 8, 2016.

We may from time to time seek to retire or purchase our outstanding debt through cash purchases and/or exchanges for equity securities, in open market purchases, privately negotiated transactions, tender offers or otherwise. Such repurchases or exchanges, if any, will depend on prevailing market conditions, our liquidity requirements, contractual restrictions and other factors. The amounts involved may be material. As of June 30, 2016, Crestwood Midstream was in compliance with all of its debt covenants applicable to the Crestwood Midstream credit facility and its senior notes.

Cash Flows

The following table provides a summary of Crestwood Equity's cash flows by category (in millions):

	Six Months Ended
	June 30,
	2016			2015
Net cash provided by operating activities	$	193.0		$	211.1
Net cash provided by (used in) investing activities	865.8			(108.4		)
Net cash used in financing activities	(1,058.4		)	(110.2		)

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Operating Activities

Our operating cash flows decreased approximately $18.1 million during the six months endedJune 30, 2016 compared to the same period in 2015 primarily due to a $235.1 million decrease in operating revenues primarily from our gathering and processing and marketing, supply and logistics segments' operations described above, partially offset by lower costs of product/services sold of approximately $175.8 million primarily due to the effect of lower commodity prices on our gathering and processing and marketing, supply and logistics segments' operations described above. In addition, we experienced lower operations and maintenance and general and administrative expenses of approximately $13.9 million primarily due to our cost-savings initiatives implemented during 2015. The decrease in net operating cash flows described above, was partially offset by a $25.3 million net cash inflow from working capital primarily resulting from lesser working capital requirements of our NGL and crude trucking operations.

Investing Activities

The energy midstream business is capital intensive, requiring significant investments for the acquisition or development of new facilities. We categorize our capital expenditures as either:

• growth capital expenditures, which are made to construct additional assets, expand and upgrade existing systems, or acquire additional assets; or

• maintenance capital expenditures, which are made to replace partially or fully depreciated assets, to maintain the existing operating capacity of our assets, extend their useful lives or comply with regulatory requirements.

The following table summarizes our capital expenditures for the six months endedJune 30, 2016 (in millions). We have identified additional growth capital project opportunities for each of our reporting segments. We expect our 2016 capital expenditures to be limited to previously committed contractual projects around our existing asset footprint. Additional commitments or expenditures will be made at our discretion, and any discontinuation of the construction of these projects will likely result in less future cash flows and earnings.

Growth capital	$	59.0
Maintenance capital	7.8
Other (1)	9.4
Purchases of property, plant and equipment	76.2
Reimbursements of property, plant and equipment	(10.7		)
Net	$	65.5

(1) Represents gross purchases of property, plant and equipment that are reimbursable by third parties.

In addition to our capital expenditures described in the table above, our cash flows from investing activities were also impacted by capital contributions of approximately $6 million and $28 million to our unconsolidated affiliates during the six months endedJune 30, 2016 and 2015. On June 3, 2016, we contributed to Stagecoach Gas the entities owning the NE S&T assets, CEGP contributed $945 million to Stagecoach Gas in exchange for a 50% equity interest in Stagecoach Gas, and Stagecoach Gas distributed to Crestwood Northeast the net cash proceeds of approximately $942 million received from CEGP. For a further discussion of investments in our unconsolidated affiliates, see Item 1. Financial Statements, Note 4.

Financing Activities

Significant items impacting our financing activities during the six months endedJune 30, 2016 and 2015, included the following:

Equity Transactions

• Increase in distributions to partners of approximately $85.5 million during the six months ended June 30, 2016 compared to the same period in 2015 due to an increase in the number of limited partner units outstanding primarily due to the Simplification Merger; and

58

• Decrease in distributions to non-controlling partners of approximately $144.8 million during the six months ended June 30, 2016 compared to the same period in 2015 primarily due to the Simplification Merger.

Debt Transactions

• $46.6 million increase in net repayments of amounts outstanding under our credit facilities primarily due to the repayment of our CEQP credit facility in 2015;

• $313 million repayments of a portion of 2020 and 2022 Senior Notes; and

• $688.3 million net proceeds from Crestwood Midstream's issuance of the 2023 Senior Notes in March 2015.

59

Item 3. Quantitative and Qualitative Disclosures About Market Risk

Our interest rate risk and commodity price and market risks are discussed in our 2015 Annual Report on Form 10-K and there have been no material changes in those exposures from December 31, 2015 to June 30, 2016. Below is an update of our credit risk related to one of our gathering and processing customers.

We continue to closely monitor our producer customer base since a majority of our customers in our gathering and processing segment and storage and transportation segment are either not rated by the major rating agencies or had below investment grade credit ratings. As noted in Item 2. Management's Discussion and Analysis of Financial Condition and Results of Operations, on April 6, 2016, Quicksilver sold its U.S. oil and gas assets to BlueStone. As a result of this sale, we no longer have any credit risk related to Quicksilver and Quicksilver has paid all final amounts billed to them.

Item 4. Controls and Procedures

Disclosure Controls and Procedures

As of June 30, 2016, Crestwood Equity and Crestwood Midstream carried out an evaluation under the supervision and with the participation of their respective management, including the Chief Executive Officer and Chief Financial Officer of their General Partners, as to the effectiveness, design and operation of our disclosure controls and procedures (as defined in the Securities Exchange Act of 1934, as amended (Exchange Act) Rules 13a-15(e) and 15d-15(e)). Crestwood Equity and Crestwood Midstream maintain controls and procedures designed to provide reasonable assurance that information required to be disclosed in their respective reports that are filed or submitted under the Exchange Act of 1934, as amended, are recorded, processed, summarized and reported within the time periods specified by the rules and forms of the SEC, and that information is accumulated and communicated to their respective management, including the Chief Executive Officer and Chief Financial Officer of their General Partners, as appropriate, to allow timely decisions regarding required disclosure. Such management, including the Chief Executive Officer and Chief Financial Officer of their General Partners, do not expect that the disclosure controls and procedures or the internal controls will prevent and/or detect all errors and all fraud. A control system, no matter how well conceived and operated, can provide only reasonable, not absolute, assurance that the objectives of the control system are met. Further, the design of a control system must reflect the fact that there are resource constraints, and the benefits of controls must be considered relative to their costs. Crestwood Equity's and Crestwood Midstream's disclosure controls and procedures are designed to provide reasonable assurance of achieving their objectives and our Chief Executive Officer and Chief Financial Officer of their General Partners concluded that our disclosure controls and procedures were effective at the reasonable assurance level as of June 30, 2016.

Changes in Internal Control over Financial Reporting

There were no changes to Crestwood Equity's or Crestwood Midstream's internal control over financial reporting during the three months endedJune 30, 2016 that have materially affected, or are reasonably likely to materially affect Crestwood Equity's or Crestwood Midstream's internal control over financial reporting.

60

PART II – OTHER INFORMATION

Item 1. Legal Proceedings

Part I, Item 1. Financial Statements, Note 10 to the Consolidated Financial Statements, of this Form 10-Q is incorporated herein by reference.

Item 1A. Risk Factors

Our business faces many risks. Any of the risks discussed below or elsewhere in this Form 10-Q or our other SEC filings could have a material impact on our business, financial position or results of operations. Additional risks and uncertainties not presently known to us or that we currently believe to be immaterial may also impair our business operations. For a detailed discussion of the risk factors that should be understood by any investor contemplating investment in our common units, please refer to Part I, Item 1A. Risk Factors in our 2015 Annual Report on Form 10-K and our Quarterly Report on Form 10-Q for the period ended March 31, 2016.

Item 2. Unregistered Sales of Equity Securities and Use of Proceeds

None.

Item 3. Defaults Upon Senior Securities

None.

Item 4. Mine Safety Disclosures

Not applicable.

Item 5. Other Information

None.

61

Item 6. Exhibits

Exhibit Number	Description
2.1	Contribution Agreement, dated as of April 20, 2016, by and between Crestwood Pipeline and Storage Northeast LLC and Con Edison Gas Pipeline and Storage Northeast, LLC (incorporated by reference to Exhibit 2.1 to Crestwood Equity Partners LP's Form 8-K filed on April 22, 2016)
3.1	Certificate of Limited Partnership of Inergy, L.P. (incorporated by reference to Exhibit 3.1 to Inergy, L.P.'s Registration Statement on Form S-1 filed on March 14, 2001)
3.2	Certificate of Correction of Certificate of Limited Partnership of Inergy, L.P. (incorporated by reference to Exhibit 3.1 to Inergy, L.P.'s Form 10-Q filed on May 12, 2003)
3.3	Amendment to the Certificate of Limited Partnership of Crestwood Equity Partners LP (the “Company”) (f/k/a Inergy, L.P.) dated as of October 7, 2013 (incorporated herein by reference to Exhibit 3.2 to Crestwood Equity Partners LP's Form 8-K filed on October 10, 2013)
3.4	Certificate of Formation of Inergy GP, LLC (incorporated by reference to Exhibit 3.5 to Inergy, L.P.'s Registration Statement on Form S-1/A filed on May 7, 2001)
3.5	Certificate of Amendment of Crestwood Equity GP LLC (the “General Partner”) (f/k/a Inergy GP, LLC) dated as of October 7, 2013 (incorporated by reference to Exhibit 3.3A to Crestwood Equity Partners LP's Form 10-Q filed on November 8, 2013)
3.6	First Amended and Restated Limited Liability Company Agreement of Inergy GP, LLC dated as of September 27, 2012 (incorporated by reference to Exhibit 3.1 to Inergy, L.P.'s Form 8-K filed on September 27, 2012)
3.7	Amendment No. 1 to the First Amended and Restated Limited Liability Company Agreement of the General Partner dated as of October 7, 2013 (incorporated by reference to Exhibit 3.4A to Crestwood Equity Partners LP's Form 10-Q filed on November 8, 2013)
3.8	Fifth Amended and Restated Agreement of Limited Partnership of Crestwood Equity Partners LP dated as of April 11, 2014 (incorporated herein by reference to Exhibit 3.1 to Crestwood Equity Partners LP's Form 8-K filed on April 11, 2014)
3.9	First Amendment to the Fifth Amended and Restated Agreement of Limited Partnership of Crestwood Equity Partners LP entered into and effective as of September 30. 2015 (incorporated by reference to Exhibit 3.1 to Crestwood Equity Partner LP’s Form 8-K filed on October 1, 2015)
3.10	Second Amended and Restated Agreement of Limited Partnership of Crestwood Midstream Partners LP, dated as of September 30, 2015 (incorporated by reference to Exhibit 3.1 to Crestwood Midstream Partners LP's Form 8-K filed on September 30, 2015)
3.11	Certificate of Formation of NRGM GP, LLC (incorporated herein by reference to Exhibit 3.7 to Inergy Midstream, L.P.'s Form S-1/A filed on November 21, 2011)
3.12	Amended and Restated Limited Liability Company Agreement of NRGM GP, LLC, dated December 21, 2011 (incorporated herein by reference to Exhibit 3.2 to Inergy Midstream, L.P.'s Form 8-K filed on December 22, 2011)
3.13	Amendment No. 1 to the Amended and Restated Limited Liability Company Agreement of Crestwood Midstream GP LLC (f/k/a NRGM GP, LLC) (incorporated herein by reference to Exhibit 3.39 to Crestwood Midstream Partners LP's Form S-4 filed on October 28, 2013)
*4.1	Supplemental Indenture, dated as of June 3, 2016, among Crestwood Midstream Partners LP, Crestwood Midstream Finance Corp., the Guarantors named therein and U.S. Bank National Association, as trustee, to the Indenture, dated as of November 8, 2013, relating to the 6.125% Senior Notes due 2022 and the Indenture, dated as of March 23, 2015, relating to the 6.25% Senior Notes due 2023.
10.1	Guaranty, dated as of April 20, 2016, made by Crestwood Equity Partners LP in favor of Con Edison Gas Pipeline and Storage Northeast, LLC (incorporated by reference to Exhibit 10.1 to Crestwood Equity Partners LP's Form 8-K filed on April 22, 2016)
10.2	Amendment to Amended and Restated Credit Agreement, dated as of April 20, 2016, among Crestwood Midstream Partners LP, as borrower, certain guarantors and financial institutions party thereto, and Wells Fargo Bank, National Association, as administrative agent and collateral agent (incorporated by reference to Exhibit 10.2 to Crestwood Equity Partners LP's Form 8-K filed on April 22, 2016)

62

*†10.3	Gas Gathering Agreement, dated as of April 6, 2016, among Cowtown Pipeline Partners L.P., as Gatherer, and BlueStone Natural Resources II, LLC, as Producer
*†10.4	Gas Gathering and Processing Agreement, dated as of April 6, 2016, among BlueStone Natural Resources II, LLC, as Producer, Cowtown Pipeline Partners L.P., as Gatherer, and Cowtown Gas Processing Partners LP, as Processor
*†10.5	Gas Gathering Agreement, dated as of April 6, 2016, among BlueStone Natural Resources II, LLC, as Producer, and Cowtown Pipeline Partners L.P., as Gatherer
*†10.6	Letter Agreement to Gathering and Processing Agreements, dated as of April 6, 2016, among Cowtown Pipeline Partners L.P., Cowtown Gas Processing Partners L.P. and BlueStone Natural Resources II, LLC
*12.1	Computation of ratio of earnings to fixed charges - Crestwood Equity Partners LP
*12.2	Computation of ratio of earnings to fixed charges - Crestwood Midstream Partners LP
*31.1	Certification of Chief Executive Officer of Crestwood Equity Partners LP pursuant to Section 302 of the Sarbanes-Oxley Act of 2002
*31.2	Certification of Chief Financial Officer of Crestwood Equity Partners LP pursuant to Section 302 of the Sarbanes-Oxley Act of 2002
*31.3	Certification of Chief Executive Officer of Crestwood Midstream Partners LP pursuant to Section 302 of the Sarbanes-Oxley Act of 2002
*31.4	Certification of Chief Financial Officer of Crestwood Midstream Partners LP pursuant to Section 302 of the Sarbanes-Oxley Act of 2002 - Crestwood Midstream Partners LP
*32.1	Certification of Chief Executive Officer of Crestwood Equity Partners LP pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002
*32.2	Certification of Chief Financial Officer of Crestwood Equity Partners LP pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002
*32.3	Certification of Chief Executive Officer of Crestwood Midstream Partners LP pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002
*32.4	Certification of Chief Financial Officer of Crestwood Midstream Partners LP pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002
**101.INS	XBRL Instance Document
**101.SCH	XBRL Taxonomy Extension Schema Document
**101.CAL	XBRL Taxonomy Extension Calculation Linkbase Document
**101.LAB	XBRL Taxonomy Extension Label Linkbase Document
**101.PRE	XBRL Taxonomy Extension Presentation Linkbase Document
**101.DEF	XBRL Taxonomy Extension Definition Linkbase Document

*	Filed herewith
**	Pursuant to Rule 406T of Regulation S-T, the Interactive Data Files on Exhibit 101 hereto are deemed not filed or part of a registration statement or prospectus for purposes of Sections 11 or 12 of the Securities Act of 1933, as amended, are deemed not filed for purposes of Section 18 of the Securities and Exchange Act of 1934, as amended, and otherwise are not subject to liability under those sections.
†	Filed under confidential treatment request

63

SIGNATURE

Pursuant to the requirements of the Securities Exchange Act of 1934, the registrant has duly caused this report to be signed on its behalf by the undersigned, thereunto duly authorized.

		CRESTWOOD EQUITY PARTNERS LP
		By:	CRESTWOOD EQUITY GP LLC
			(its general partner)
Date:	August 4, 2016	By:	/s/ ROBERT T. HALPIN
			Robert T. Halpin
			Senior Vice President and Chief Financial Officer
			(Duly Authorized Officer and Principal Financial Officer)
		CRESTWOOD MIDSTREAM PARTNERS LP
		By:	CRESTWOOD MIDSTREAM GP LLC
			(its general partner)
Date:	August 4, 2016	By:	/s/ ROBERT T. HALPIN
			Robert T. Halpin
			Senior Vice President and Chief Financial Officer
			(Duly Authorized Officer and Principal Financial Officer)

64

EX-4.1

Exhibit 4.1

SUPPLEMENTAL INDENTURE

US 4302682v.2

THIS SUPPLEMENTAL INDENTURE (this “Supplemental Indenture”), is dated as of June 3, 2016, among Crestwood Midstream Partners LP, a Delaware limited partnership (the “Company”), Crestwood Midstream Finance Corporation, a Delaware corporation (the “Co-Issuer” and, together, with the Company, the “Issuers”), each existing Guarantor under each of the Indentures referred to below and U.S. Bank National Association, as trustee under each of the Indentures referred to below (the “Trustee”).

WITNESSETH:

WHEREAS, the Issuers and the existing Guarantors have heretofore executed and delivered to the Trustee (i) an indenture (as it may have been heretofore amended or supplemented, the “2013 Indenture”), dated as of November 8, 2013, providing for the issuance of the Issuers’ 6.125% Senior Notes due 2022 (the “2022 Notes”) and (ii) an indenture (as it may have been heretofore amended or supplemented, the “2015 Indenture” and, together with the 2013 Indenture, the “Indentures”), dated as of March 23, 2015, providing for the issuance of the Issuers’ 6.25% Senior Notes due 2023 (the “2023Notes” and, together with the 2022 Notes, the “Notes”);

WHEREAS, Section 10.05 of each Indenture provides that if the Company designates any Material Restricted Subsidiary that is a Guarantor to be an Unrestricted Subsidiary in accordance with the applicable provisions of such Indenture, then the Note Guarantee of such Guarantor will be released;

WHEREAS, in accordance with the provisions of Section 4.16 of each Indenture the Board of Directors of the Company has heretofore designated each of Arlington Storage Company, LLC, Crestwood Gas Marketing LLC, Crestwood Pipeline and Storage Northeast LLC, Crestwood Pipeline East LLC, Crestwood Storage Inc., Stagecoach Gas Services LLC, Stagecoach Operating Services LLC and Stagecoach Pipeline & Storage Company, LLC (collectively, the “Released Guarantors”) to be an Unrestricted Subsidiary;

WHEREAS, pursuant to Section 9.01(8) of each of the Indentures, the Trustee, the Issuers and the existing Guarantors are authorized to execute and deliver this Supplemental Indenture, without the consent on any Holder of any of the Notes, to release any Guarantor from its Note Guarantee.

NOW, THEREFORE, in consideration of the foregoing and for other good and valuable consideration, the receipt of which is hereby acknowledged, the Issuers, the Guarantors and the Trustee mutually covenant and agree for the equal and ratable benefit of the Holders as follows:

1.    DEFINED TERMS. Defined terms used herein without definition shall have the meanings assigned to them in the Indenture.

2.    RELEASE OF NOTE GUARANTEES. Each of the Released Guarantors is hereby unconditionally released from its Note Guarantee, and accordingly the Trustee acknowledges that the Released Guarantors are no longer parties to the Indentures.

3.    RATIFICATION OF EACH INDENTURE; SUPPLEMENTAL INDENTURE PART OF EACH INDENTURE. Except as expressly amended hereby, each Indenture is in all respects ratified and confirmed and all the terms, conditions and provisions thereof shall remain in full force and effect. This

Supplemental Indenture shall form a part of each Indenture for all purposes, and every holder of Notes heretofore or hereafter authenticated and delivered shall be bound hereby.

4.    GOVERNING LAW. THIS SUPPLEMENTAL INDENTURE SHALL BE GOVERNED BY, AND CONSTRUED IN ACCORDANCE WITH, THE LAWS OF THE STATE OF NEW YORK.

5.    COUNTERPARTS. The parties may sign any number of copies of this Supplemental Indenture. Each signed copy shall be an original, but all of them together represent the same agreement. The exchange of copies of this Supplemental Indenture and of signature pages by facsimile or PDF transmission shall constitute effective execution and delivery of this Supplemental Indenture as to the parties hereto and may be used in lieu of the original Supplemental Indenture for all purposes. Signatures of the parties hereto transmitted by facsimile or PDF shall be deemed to be their original signatures for all purposes.

6.    EFFECT OF HEADINGS. The Section headings of this Supplemental Indenture have been inserted for convenience of reference only and are not to be considered part of this Supplemental Indenture or the Indenture and will in no way modify or restrict any of the terms or provisions hereof or thereof.

7.    TRUSTEE MAKES NO REPRESENTATION. The Trustee makes no representation as to the validity or sufficiency of this Supplemental Indenture. The recitals and statements herein are deemed to be those of the Issuers and the Guarantors and not those of the Trustee, and the Trustee assumes no responsibility for their correctness.    

IN WITNESS WHEREOF, the parties hereto have caused this Supplemental Indenture to be duly executed and attested, all as of the date first above written.

CRESTWOOD MIDSTREAM PARTNERS LP

By: Crestwood Midstream GP LLC, its general partner

/s/ Steven M. Dougherty_________________

Name:    Steven M. Dougherty

Title: Senior Vice President and Chief Accounting Officer

CRESTWOOD MIDSTREAM FINANCE CORP.

/s/ Steven M. Dougherty_________________

Name:    Steven M. Dougherty

Title: Senior Vice President and Chief Accounting Officer

GUARANTORS:

ARLINGTON STORAGE COMPANY, LLC

ARROW FIELD SERVICES, LLC

ARROW MIDSTREAM HOLDINGS, LLC

ARROW PIPELINE, LLC

ARROW WATER, LLC

CENTRAL NEW YORK OIL AND GAS COMPANY, L.L.C.

CMLP TRES MANAGER LLC

CMLP TRES OPERATOR LLC

/s/ Steven M. Dougherty_________________

Name:    Steven M. Dougherty

Title: Senior Vice President and Chief Accounting Officer

COWTOWN GAS PROCESSING PARTNERS L.P.

By: Crestwood Gas Services Operating GP LLC,

its general partner

COWTOWN PIPELINE PARTNERS L.P.

By: Crestwood Gas Services Operating GP LLC,

its general partner

/s/ Steven M. Dougherty_________________

Name:    Steven M. Dougherty

Title: Senior Vice President and Chief Accounting Officer

Signature Page to Supplemental Indenture

CRESTWOOD APPALACHIA PIPELINE LLC

CRESTWOOD ARKANSAS PIPELINE LLC

CRESTWOOD CRUDE LOGISTICS LLC

CRESTWOOD CRUDE SERVICES LLC

CRESTWOOD CRUDE TERMINALS LLC

CRESTWOOD CRUDE TRANSPORTATION LLC

CRESTWOOD DAKOTA PIPELINES LLC

CRESTWOOD GAS MARKETING LLC

CRESTWOOD GAS SERVICES OPERATING GP LLC

CRESTWOOD GAS SERVICES OPERATING LLC

CRESTWOOD MARCELLUS MIDSTREAM LLC

CRESTWOOD MARCELLUS PIPELINE LLC

CRESTWOOD MIDSTREAM OPERATIONS LLC

CRESTWOOD NEW MEXICO PIPELINE LLC

CRESTWOOD OHIO MIDSTREAM PIPELINE LLC

CRESTWOOD PANHANDLE PIPELINE LLC

CRESTWOOD PIPELINE EAST LLC

CRESTWOOD PIPELINE LLC

CRESTWOOD SABINE PIPELINE LLC

CRESTWOOD STORAGE INC.

E. MARCELLUS ASSET COMPANY, LLC

FINGER LAKES LPG STORAGE, LLC

SABINE TREATING, LLC

US SALT, LLC

/s/ Steven M. Dougherty_________________

Name:    Steven M. Dougherty

Title: Senior Vice President and Chief Accounting Officer

CRESTWOOD OPERATIONS LLC
CRESTWOOD SERVICES LLC

CRESTWOOD WEST COAST LLC

CRESTWOOD SALES & SERVICES INC.

CRESTWOOD TRANSPORTATION LLC

STELLAR PROPANE SERVICE, LLC

/s/ Steven M. Dougherty_________________

Name:    Steven M. Dougherty

Title: Senior Vice President and Chief Accounting Officer

Signature Page to Supplemental Indenture

U.S. BANK NATIONAL ASSOCIATION, as Trustee

By:    /s/ Raymond S. Haverstock_______________

Name:    Raymond S. Haverstock

    Title:    Vice President

Signature Page to Supplemental Indenture

EX-10.3

PORTIONS OF THIS EXHIBIT DENOTED WITH THREE ASTERISKS (***) HAVE BEEN OMITTED PURSUANT TO A REQUEST FOR CONFIDENTIAL TREATMENT

Exhibit 10.3

GAS GATHERING AGREEMENT

BETWEEN

COWTOWN PIPELINE PARTNERS L.P. (“GATHERER”)

AND

BLUESTONE NATURAL RESOURCES II, LLC (“PRODUCER”)

Alliance Area Gathering System, Tarrant and Denton Counties, Texas

1

3230471v2

PORTIONS OF THIS EXHIBIT DENOTED WITH THREE ASTERISKS (***) HAVE BEEN OMITTED PURSUANT TO A REQUEST FOR CONFIDENTIAL TREATMENT

TABLE OF CONTENTS

1.    Definitions    1

2.    Dedication of Contract Area    6

3.    Reservations of Parties    7

4.    Receipt Point(s) and Delivery Point(s)    7

5.    System Operations; Imbalances    9

6.    Quantity; Nominations and Dispatching    10

7.    Quality    11

8.    Tests    13

9.    Measurement and Meter Testing    13

10.    Allocation of Gains, Fuel and Loss    16

11.    Fees    17

12.    Accounting, Payments and Credit Assurances    17

13.    Warranty    20

14.    Taxes    20

15.    Indemnity and Damages    20

16.    Force Majeure    23

17.    Unprofitable Operations and Rights of Termination    23

18.    Term    24

19.    Regulatory Bodies    24

20.    Disputes    25

21.    Notices and Payments    25

22.    Right to Process the Subject Gas    26

23.    Assignment    27

24.    Miscellaneous    27

EXHIBIT A – CONTRACT AREA; DEDICATED LEASES; DEDICATED WELLS

EXHIBIT B – RECEIPT POINTS AND DELIVERY POINTS

EXHIBIT C – DEHYDRATION AND CO2 TREATING SERVICES

PORTIONS OF THIS EXHIBIT DENOTED WITH THREE ASTERISKS (***) HAVE BEEN OMITTED PURSUANT TO A REQUEST FOR CONFIDENTIAL TREATMENT

GAS GATHERING AGREEMENT

THIS GAS GATHERING AGREEMENT (this “Agreement”) is made and entered into as of the Effective Date by and among COWTOWN PIPELINE PARTNERS L.P., a Texas limited partnership (“Gatherer”), and BLUESTONE NATURAL RESOURCES II, LLC, a Delaware limited liability company (“Producer”). Gatherer and Producer are sometimes individually referred to herein as a “Party” and collectively as the “Parties.”

WITNESSETH, THAT:

WHEREAS, Producer is in the business of producing gas and owns gas production from one or more wells (and one or more contemplated wells) on the lands within the Contract Area (or lands pooled therewith) and desires for Gatherer to gather such gas for redelivery to Producer or Producer’s Transporter; and

WHEREAS, Gatherer is in the business of providing natural gas gathering services along its Gathering System and desires to receive, gather and deliver such gas to Producer or Producer’s Transporter, subject to the terms and conditions herein;

NOW, THEREFORE, for good and valuable consideration the adequacy, receipt and sufficiency of which are hereby set forth and acknowledged, and for all of the representations, warranties and mutual covenants set forth herein, Gatherer and Producer agree as follows:

1.    Definitions

1.1    For the purpose of this Agreement, the following terms and expressions used herein are defined as follows:

a.    “Affiliate” shall mean, with respect to any specified Person, any other Person that directly or indirectly, through one or more intermediaries, Controls, is Controlled by, or is under common Control with, such specified Person. As used in this definition, the term “Control” (including its derivatives and similar terms) means the ownership, directly or indirectly, of fifty percent (50%) or more of the capital stock issued by a corporation, the limited liability company interests of a limited liability company or the equivalent equity interests in any other Person, the holders of which are ordinarily, in the absence of contingencies, entitled to vote for the election of directors (or Persons with management authority performing similar functions) of such Person, even though the right so to vote has been suspended by the happening of such a contingency. Gatherer acknowledges and agrees that Producer’s majority owner is a private equity sponsor that owns and controls a number of other portfolio companies engaged in the oil and gas business and that none of such other portfolio companies shall be considered an “Affiliate” under this Agreement if neither Producer nor any personnel of

PORTIONS OF THIS EXHIBIT DENOTED WITH THREE ASTERISKS (***) HAVE BEEN OMITTED PURSUANT TO A REQUEST FOR CONFIDENTIAL TREATMENT

Producer directly or indirectly direct or cause the direction of the management and policies of that company. Producer acknowledges and agrees that Gatherer is controlled by First Reserve Corporation, which owns and controls a number of other portfolio companies engaged in the oil and gas business and none of such other portfolio companies shall be considered an "Affiliate" under this Agreement if Gatherer nor any personnel of Gatherer directly or indirectly direct or cause the direction of the management and policies of that company.

b.    "Asset Purchase Agreement" shall mean that certain Asset Purchase Agreement by and among QRI, Cowtown Gas Processing L.P. and Cowtown Pipeline L.P. and Producer, dated January 22, 2016.

c.    “Btu” shall mean one British thermal unit, which is the quantity of heat required to raise one pound avoirdupois of pure water from 58.5 degrees Fahrenheit to 59.5 degrees Fahrenheit at a constant pressure of 14.73 pounds per square inch absolute.

d.    “Component” shall mean those hydrocarbon and nonhydrocarbon molecular constituents which are definable by industry standards and procedures. Such Components as used in this Agreement shall be:

N2 – Nitrogen

CO2 - Carbon Dioxide

H2S - Hydrogen Sulfide

C1 - Methane

C2 - Ethane

C3 - Propane

iC4 - Iso-butane

nC4 - Normal Butane

iC5 - Iso-pentane

nC5 - Normal Pentane

C6+ - Hexanes and Heavier Compounds

e.    “Contract Area” shall mean that area as described or outlined on Exhibit A which is attached hereto and made a part hereof for all purposes, but specifically excludes Producer’s and/or its Affiliates’ leasehold interests owned immediately prior to the Effective Date within the Contract Area but not listed on Exhibit A.

f.    “CPI Adjustment” shall mean that percentage equal to the percentage increase between:

2

PORTIONS OF THIS EXHIBIT DENOTED WITH THREE ASTERISKS (***) HAVE BEEN OMITTED PURSUANT TO A REQUEST FOR CONFIDENTIAL TREATMENT

(i)    the seasonally unadjusted consumer Price Index for Urban Wage Earners and Clerical Workers (all items), U.S. city Average (1982-84 =100), as published by the U.S. Department of Labor, Bureau of Labor Statistics (“CPI-W”) for the month of December of the second year prior to the Escalation Date; and

(ii)    the seasonally unadjusted CPI-W for the month of December immediately preceding the Escalation Date.

g.    “Day” shall mean a period of twenty-four (24) consecutive hours beginning and ending at seven o’clock a.m. Central Standard Time.

h.    “Dedicated Properties” shall mean (i) Producer’s and/or its Affiliates’ leasehold interest as of the Effective Date within the Contract Area in and to those certain oil, gas and/or mineral leases, as are listed on Exhibit A, and (ii) Producer’s and/or its Affiliates’ interests within the Contract Area in and to any new oil, gas and/or mineral lease acquired by Producer or its Affiliates after the Effective Date, provided that any wells on lands covered by such lease or lands pooled therewith and within the Contract Area are connected to the Gathering System pursuant to Section 4.4.

i.    “Delivery Points” shall mean the point(s) of interconnect between the Gathering System and the Transporter receiving the Gas, which point(s) are shown on Exhibit B which is attached hereto and made a part hereof for all purposes.

j.    “Effective Date” shall have the meaning set forth in Section 1(c) of the Letter Agreement.

k.    “Electrical Power” shall mean the electricity consumed in the operation of, and purchased from a utility or like entity which serves, the Gathering System and any of the related field facilities.

l.    “Escalation Date” shall mean January 1, 2018 and each January 1st thereafter during the Term.

m.    “Fuel and Loss” shall mean the gas volumes used or consumed in the operation of the Gathering System, which shall include, but shall in no way be limited to, (i) gas used as fuel for dehydration, compression, conditioning, blending, treating, or recompression, (ii) gas needed for line pack, (iii) gas vented during operations, (iv) lost and unaccounted for gas, and (v) any Liquefiable Hydrocarbons that become separated from the gas while the gas is in the Gathering System.

3

PORTIONS OF THIS EXHIBIT DENOTED WITH THREE ASTERISKS (***) HAVE BEEN OMITTED PURSUANT TO A REQUEST FOR CONFIDENTIAL TREATMENT

n.    “Gas” shall mean natural gas which is owned or controlled by Producer and producible from wells drilled on Dedicated Properties or lands pooled therewith within the Contract Area, including casinghead gas produced with crude oil, gas from gas wells produced in association with crude oil (associated gas), and gas from condensate wells (non-associated gas), and shall include any inerts or impurities contained therein.

o.    “Gathering Fee” shall have the meaning set forth in Section 11.1.

p.    “Gathering System” shall mean, but shall in no way be limited to, the gas gathering pipelines, fuel gas pipelines, dehydration facilities, treating facilities, compression facilities, junctions, heaters, meters, separators, electric power lines, communications cables, roads, and other related facilities and equipment, including the rights to the lands on which any part of such facilities or equipment is located, necessary to gather and transport gas from the Gathering System’s Receipt Point(s) to the Delivery Point(s), from the inlet flange of the pipeline metering facility installed at the Receipt Point(s) up to the upstream flange of the metering facility at the Delivery Point(s), and shall include any expansion of the Gathering System as provided in Section 4.4.

q.    “GPM” shall mean gallons per thousand cubic feet.

r.    “Law” means any law, statute, code, ordinance, order, determination, rule, regulation, judgment, decree, injunction, franchise, permit, certificate, license, authorization or other directive or requirement of (i) the United States of America, (ii) any state, county, municipality, or other governmental subdivision within the United States of America, and (iii) any court or any governmental department, commission, board, bureau, agency, or other instrumentality of the United States of America or of any state, county, municipality, or other governmental subdivision within the United States of America.

s.    “Letter Agreement” means that certain letter agreement executed by the Parties contemporaneously with this Agreement.

t.    “Lift Gas” shall mean the Gas, reserved by Producer under Section 3.2, used by Producer for gas lift operations in the Contract Area, measured in MCFs at the existing Alliance CMU meter station number ALSA020MU.

u.    “Liquefiable Hydrocarbons” shall mean ethane, propane, isobutanes, normal butanes, iso-pentanes, normal pentanes, hexanes and

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heavier hydrocarbons, and incidental methane, or any mixtures thereof, which may be recovered or extracted in the Gathering System.

v.    “MCF” shall mean 1,000 standard cubic feet of gas.

w.    “MMBtu” shall mean 1,000,000 Btus.

x.    “MMCF” shall mean 1,000,000 standard cubic feet of gas.

y.    “MMCFD” shall mean 1,000,000 standard cubic feet of gas per day.

z.    “Month,” “billing month,” “period,” and “accounting period” shall mean the period beginning at seven o’clock a.m. on the first day of a calendar month and ending at seven o’clock a.m. on the first day of the next succeeding calendar month.

aa.    “Person” means any natural person, corporation, limited liability company, partnership, joint venture, association, cooperative, or other entity.

bb.    “psia” shall mean pounds per square inch absolute.

cc.    “psig” shall mean pounds per square inch gauge.

dd.    “Receipt Points” shall mean the inlet flange of Gatherer’s metering facilities located at or near each of Producer’s wells located within the Contract Area or such other point as may be mutually agreed upon by the Parties. The Gathering System’s Receipt Point(s) are listed on Exhibit B to this Agreement which is attached hereto and made a part hereof for all purposes and which may be amended from time to time to reflect the addition or deletion of a Receipt Point.

ee.    “SCF” or “standard cubic foot of gas” shall mean the amount of gas necessary to fill a cubic foot of space when the gas is at a pressure of 14.65 pounds per square inch absolute and a temperature of 60 degrees Fahrenheit.

ff.    “Senior Executives” shall have the meaning set forth in Section 20.1.

gg.    “Subject Gas” means the Gas other than natural gas owned by Tokyo Gas and subject to the Tokyo Gas Gathering Agreement.

hh.    “Tokyo Gas” shall mean Tokyo Gas, Co., Ltd.

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ii.    “Tokyo Gas Gathering Agreement” shall mean that certain Gas Gathering Agreement, dated as of December 1, 2009, among Gatherer, Quicksilver Resources Inc. and Tokyo Gas, as amended, modified or otherwise supplemented.

jj.    “Term” shall have the meaning set forth in Section 18.

kk.    “Total Delivered Quantities” shall have the meaning set forth in Section 10.1.

ll.    “Transporter” shall mean the receiving pipeline(s) downstream of the Gathering System into which the Subject Gas gathered hereunder is to be delivered at the Delivery Point(s).

1.2    Any reference to any federal, state, or local statute or law will be deemed to refer to such statute or law, as amended, and also to refer to all rules and regulations promulgated thereunder, unless the context requires otherwise. Any reference to a Party will also include such Party’s permitted successors and assigns. All defined terms in this Agreement shall be equally applicable to the singular and plural forms of the terms so defined. The words “including,” “includes,” and “include” will be deemed to be followed by the phrase “without limitation.” All personal pronouns used in this Agreement, whether used in the masculine, feminine or neuter gender, will include all other genders; the singular will include the plural, and vice versa, unless the context requires otherwise. All references herein to an Exhibit, Schedule, Section, subsection, paragraph, subparagraph or other subdivision will refer to the corresponding Exhibit, Schedule, Section, subsection, paragraph, subparagraph or other subdivision of this Agreement unless specific reference is made to an exhibit, schedule, section, subsection, paragraph, subparagraph or other subdivision of another document or instrument. The terms “herein,” “hereby,” “hereunder,” “hereof,” “hereinafter,” and other equivalent words refer to this Agreement in its entirety and not solely to the particular portion of the Agreement in which such word is used.

2.    Dedication & Commitment

2.1    Subject to the terms and provisions hereof, Producer (a) dedicates the Dedicated Properties to the Gathering System for gathering by Gatherer and (b) commits to deliver or cause to be delivered at Gatherer’s Receipt Point(s) the total volume of Subject Gas from wells now or hereafter drilled on the lands covered by the Dedicated Properties (or lands pooled therewith), in each case excluding the Subject Gas reserved or utilized by Producer in accordance with the terms of Section 3. Any transfer by Producer of its right, title, or interest in the Dedicated Properties or in the Subject Gas owned by Producer, or in an oil and gas lease, fee mineral interest or other agreement, interest or right which creates or gives rise to Producer’s interest in the Subject Gas owned by Producer, to a third party, whether by farmout,

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contract, or otherwise, shall be subject to this Agreement. In addition, Producer will notify any person to whom Producer transfers all or a portion of its right, title, or interest in or out of the Dedicated Properties or the Subject Gas owned by Producer that such Dedicated Properties, and the Subject Gas owned by Producer located under the lands covered by such Dedicated Properties, is dedicated pursuant to the terms of this Agreement to be gathered by Gatherer. Producer will notify Gatherer of any such transfer within 10 days of the effective date. Failure of Producer to comply with the foregoing shall not affect Gatherer’s rights herein or the dedication being binding on successors or assignees.

2.2    Gas shall be delivered to the Receipt Point(s) after standard mechanical separation by Producer for the removal of free water and free liquid hydrocarbons, but shall not otherwise be processed by Producer for the removal of Liquefiable Hydrocarbons.

2.3    Gatherer agrees that subject to the provisions hereof, it will receive the Subject Gas from the Receipt Point(s), provide dehydration, compression and treating services, and will cause the redelivery of the Subject Gas, less Producer’s pro rata share of Fuel and Loss, to Producer or Producer’s Transporter at the Delivery Point(s).

2.4    To the extent Producer acquires any additional leasehold interests within the Contract Area that are subject to an existing services contract with Gatherer, such interests shall remain subject to such contract until the expiration or termination of such contract unless Producer and Gatherer mutually agree to a release under the terms of such contract and dedicate and commit the interests to this Agreement. To the extent Producer acquires any additional leasehold interests within the Contract Area that are subject to an existing dedication, such interests shall not be subject to this Agreement for so long as the prior dedication remains in effect without Producer exercising any extension rights or entering into an agreement to extend the duration of the prior dedication.

2.5    Producer hereby represents and warrants to Gatherer, the following: (i) Exhibit A contains true, accurate, and complete descriptions of all oil, gas and/or mineral leases within the Contract Area acquired from QRI pursuant to the terms to Asset Purchase Agreement and owned by Producer or its Affiliates as of the Effective Date, which are dedicated and committed to the Gathering System as of the Effective Date; and (ii) Producer or its Affiliates have the right to dedicate and commit such oil, gas and/or minerals leases to the Gathering System. To the extent that Producer did acquire from QRI pursuant to the Asset Purchase Agreement oil, gas and/or mineral leases within the Contract Area which have been omitted from Exhibit A, such oil, gas and/or mineral leases shall be deemed to be included on Exhibit A and the Parties shall promptly amend Exhibit A to add such omitted oil, gas and/or mineral leases. Such amendments to Exhibit A shall be Gatherer’s sole

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and exclusive remedy for Producer’s breach of any representation or warranty in this Section 2.5.

2.6    Either Party may record a mutually agreeable form of memorandum of this Agreement in the official public records of the counties located within the Contract Area.

3.    Reservations of Parties

3.1    Producer reserves all liquid hydrocarbons, oil, or condensate removed by Producer by means of mechanical gas-liquid separators (including heater-treaters), drips, and/or lines from the Gas prior to delivery to Gatherer. If mechanical cooling is performed by Producer to meet the temperature specifications of this Agreement, Producer shall not reduce the temperature of the Gas below 60 degrees Fahrenheit.

3.2    Producer reserves all Gas that may be required for cycling, repressuring, pressure maintenance, and gas lift operations with respect to gas reservoirs on the premises committed hereunder; provided, however, that the Gas used in such operations shall be subject to the terms of this Agreement (to the extent that such Gas can be economically saved) and delivered to Gatherer following the cessation of such operations.

3.3    Producer reserves that amount of Gas which is required for above ground development and operation within the Contract Area.

3.4    Producer expressly reserves the right to deliver or furnish to Producer’s lessor such Gas as required to satisfy the terms of Producer’s oil and gas leases.

4.    Receipt Point(s) and Delivery Point(s)

4.1    Producer shall be responsible for all arrangements and, at its own expense, shall construct, equip, maintain, and operate all facilities (including, but not limited to, all necessary separation, dehydration, and/or compression equipment), necessary to deliver the Gas to Gatherer at the Receipt Point(s) at such pressure as is required and sufficient to enter the Gathering System, but not to exceed 1,200 psig.

4.2    Subject to the then current operating conditions on the Gathering System, outages or restrictions due to maintenance or force majeure, or any interruption permitted under this Agreement, Gatherer will use commercially reasonable efforts to operate its central compression facility(ies) existing as of the Effective Date to maximize volumes across its Gathering System. If, in addition to the foregoing, Gatherer has available compression capacity, it will use commercially

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reasonable efforts to provide optimal Receipt Point(s) pressure service to Producer, including in response to any written request(s) made by Producer to Gatherer, and other third parties on the Gathering System on a not unduly discriminatory basis. In the event Gatherer desires to remove any compression unit(s) existing as of the Effective Date before the tenth anniversary of the Effective Date, Gatherer shall obtain Producer’s consent, which consent shall not to be unreasonably delayed or withheld, before removing such compression unit(s). For the avoidance of doubt, Gatherer acknowledges and agrees that it shall not be unreasonable if Producer withholds consent because it would adversely impact current operations, or if Producer conditions its consent on the requirement that Gatherer add back compression in the future if Producer’s drilling or development plans so require.

4.3    Subject to Sections 4.1 and 5.1, at any time during the term of this Agreement, Producer may request that the Parties enter into negotiations to add compression to the Gathering System to reduce or maintain the pressure at which Producer must enter the Gathering System and to determine the mutually agreeable commercial terms and conditions under which Gatherer would install and operate such additional compression, and Gatherer and Producer agree to participate fully and reasonably in such negotiations.

4.4    Gatherer, at Producer’s expense, shall (i) install, construct and equip all meters and facilities necessary to measure the Gas at the Receipt Point(s), and (ii) secure any right-of-way, easements, and permits as are necessary and appropriate to construct, operate, maintain and access such facilities. Gatherer, at its own expense, shall thereafter maintain and operate such facilities throughout the Term of this Agreement.

4.5    If Producer acquires additional mineral interests or oil, gas and/or mineral leases within the Contract Area, Producer shall notify Gatherer with any proposed reasonable supporting documentation (including the location of any existing or proposed well(s)) sufficient for Gatherer to evaluate whether building an expansion of the Gathering System to any existing or proposed well on such new mineral or leasehold interests would be economic pursuant to the fee structure set forth in this Agreement. Gatherer, in its sole and absolute discretion, may decline to construct any Gathering System expansion to connect the Gathering System to any wells located on lands covered by such new mineral or leasehold interests or lands pooled therewith. Within sixty (60) Days after receiving notice (or, if later, reasonable supporting documentation) from Producer, Gatherer may either elect to construct the expansion pursuant to the fee structure set forth in this Agreement or propose an alternative fee structure that Gatherer deems economic. If Gatherer elects to construct the expansion pursuant to the fee structure set forth in this Agreement, Gatherer shall complete such expansion and be ready to accept Subject Gas as follows: (a) for an expansion requiring two (2) or fewer miles to connect the well(s) to the Gathering System, no later than one hundred and twenty (120) days; and (b) for all other expansions, as soon as reasonably practicable using diligent

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efforts; provided that the foregoing time periods in (a) and (b) shall be extended day-for-day for the duration of any events of force majeure affecting Gatherer’s performance, after receiving notice (or, if later, reasonable supporting documentation) from Producer. In the event such expansion is not completed and accepting Subject Gas within such time period, the affected new mineral or leasehold interest and land pooled therewith (but excluding any Dedicated Properties already connected to Gatherer’s System) shall, at Producer’s election by written notice to Gatherer delivered within five (5) days following such period of time, no longer be Dedicated Properties hereunder or subject to this Agreement in any manner whatsoever. If Gatherer proposes an alternative fee structure, then Producer may elect in its sole and absolute discretion to either (i) construct the connection to the Gathering System at Producer’s sole cost and expense, (ii) amend this Agreement to provide for the alternative fee structure proposed by Gatherer, in which case Gatherer shall construct the connection; or (iii) not connect such leasehold interests the Gathering System. If Gatherer elects to not connect, then the new mineral or leasehold interest and land pooled therewith (but excluding any Dedicated Properties already connected to Gatherer’s System) shall no longer be Dedicated Properties hereunder or subject to this Agreement in any manner whatsoever. If Producer elects to build the connection itself, such Gathering System expansion must meet all of Gatherer's specifications, and Gatherer will be responsible for the meter station and connection to the existing Gathering System. Gatherer may, at its election, but only within two years (2) of the initial delivery of production from the connection to the Gathering System, acquire the ownership of the connecting facilities installed by Producer by reimbursing Producer for the actual cost with no allowance for inflation or depreciation. In such event, Producer agrees to execute all assignments or contracts deemed reasonably necessary to accomplish the transfer to Gatherer of title to the Gathering System expansion, including rights-of-way and easements, on an “as is, where is” basis and with other terms and conditions customary for the purchase and sale of midstream assets within the Contract Area.

4.6    Gatherer agrees to deliver the Subject Gas to Producer or Producer’s nominated Transporter, less Producer’s pro rata share of Fuel and Loss, at the Delivery Point(s). The Subject Gas shall be deemed to have been delivered to Producer or to the Transporter on Producer’s behalf at the Delivery Point(s), and to have passed through the Delivery Point(s), when the Subject Gas passes through the upstream flange of the metering facility at the Delivery Point(s).

5.    System Operations; Imbalances

5.1    Gatherer shall retain full operational control of the Gathering System and shall at all times be entitled to schedule deliveries and to operate its facilities in a manner consistent with safe and prudent operating practices under the conditions which may exist from time to time. Accordingly, Gatherer may interrupt the gathering of the Subject Gas as necessary to test, alter, modify, enlarge, expand, maintain or repair any facility or property comprising any part of or appurtenant to

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the Gathering System; provided, however, during the time period during such interruption, Producer may dispose of the Subject Gas as it see fit and, if such interruption continues for a period of one hundred and twenty (120) consecutive days, extended day-for-day for the duration of any events of force majeure, Producer shall have the option, exercised solely at its discretion, to permanently release the Subject Gas produced from the affected well(s) by providing to Gatherer thirty (30) days' advance written notice, other than to the extent that prior to the expiration of such notice interruptions have ceased. It is understood and agreed by the Parties that in order for Gatherer to maintain efficiency in the Gathering System, it will be necessary to maintain a uniform rate of flow of the Gas to the Gathering System from all sources during each twenty-four (24) hour period. Therefore, Producer agrees that it will cooperate with Gatherer in regulating the flow rate of the Gas and in establishing a producing schedule to deliver on a commercially reasonable basis the Gas at a uniform and continuous flow rate. In the event that Gatherer enters into an operational balancing agreement with Producer’s Transporter, Producer hereby agrees to be bound by the terms set forth therein.

5.2    It is acknowledged that, because of dispatching and other causes, certain imbalances may occur between the MMBtus of the Subject Gas delivered hereunder by Gatherer to or for the account of Producer at the Delivery Point(s) and the MMBtus of the Subject Gas received from or on behalf of Producer at the Receipt Point(s). Such imbalances, if any, shall be eliminated as soon as practical after each such occurrence; provided, however, Gatherer shall not be required to eliminate any imbalance during any month in which the value of the Subject Gas received or delivered, as reasonably determined by Gatherer, is not representative of the market value of natural gas when the imbalance occurred. Any imbalance remaining following the termination of this Agreement shall be eliminated during the Month following the Month in which termination occurs or as soon as practicable thereafter. Producer authorizes the operator of each of Producer’s wells to be its agent for the purpose of providing Gatherer with instructions to adjust allocations of the Subject Gas attributable to that well for gas balancing purposes. Producer represents that it has the right to make any such adjustments and that such adjustments are correct. Gatherer may adjust the Subject Gas allocated to that well in accordance with these instructions but Gatherer is not obligated to do so at any time. Gatherer shall notify Producer of any such allocation change implemented by Gatherer at Producer’s operator’s instructions.

5.3    The Parties acknowledge that the Gathering System is connected to the facilities of Transporter and, as a result, Gatherer shall be, from time to time, subject to certain requirements imposed by Transporter. Accordingly, Gatherer shall have the right under this Agreement to require Producer to comply with the pipeline requirements of Transporter. PRODUCER AGREES TO INDEMNIFY, DEFEND, AND HOLD GATHERER HARMLESS FROM PRODUCER’S FAILURE TO COMPLY WITH TRANSPORTER’S REQUIREMENTS.

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6.    Quantity; Nominations and Dispatching

6.1    The Parties acknowledge and agree that natural gas (including Gas) which is owned by Tokyo Gas is subject to the Tokyo Gas Gathering and Processing Agreement and may be delivered to Gatherer by Producer pursuant to a joint operating agreement between Producer and Tokyo Gas.

6.2    Subject to Gathering System capacity, Gatherer shall gather that volume of Subject Gas legally allowed to be produced which is attributable to the interest owned or controlled by Producer in wells drilled on lands within the Contract Area or lands pooled therewith; provided, Producer or Producer’s Transporter or nominee will accept the Subject Gas redelivered on Producer’s behalf at the Delivery Point(s). Gatherer may, from time to time, find it necessary to shut off entirely or restrict the flow of gas to the Gathering System notwithstanding anything herein to the contrary and, in such event, Gatherer shall not be liable to Producer for the resulting effect thereof; provided, however, during the time period during such shut off or restriction, Producer may dispose of the Subject Gas as it see fit and if such shut off or restriction continues for a period of ninety (90) consecutive days, extended day-for-day for the duration of events of force majeure affecting Gatherer’s performance, then the Subject Gas produced from the affected well(s) shall, at Producer’s election by no less than thirty days’ prior written notice to Gatherer, no longer be Dedicated Properties hereunder or subject to this Agreement in any manner whatsoever unless Gatherer has remedied the cause of such shut off or restriction prior to the date set forth in Producer’s notice. Gatherer shall provide Producer reasonable prior notice of any shut down due to routine maintenance and shall prudently work to minimize the amount of such downtime.

6.2    Producer shall make all nominations to Transporter in accordance with Transporter’s nomination procedures, and shall make any and all other arrangements necessary for Transporter to receive the Subject Gas at the Delivery Point(s). Producer shall nominate to Gatherer in writing, not less than three (3) business Days prior to the first day of each Month during the Term of this Agreement, the daily quantity of the Subject Gas and Gas owned by Tokyo Gas (expressed in MCFs and MMBtus) that Producer shall deliver to Gatherer at the Receipt Point(s) for gathering during such Month and that Producer or Producer’s Transporter or nominee shall accept at the Delivery Point(s). The Parties acknowledge and agree that the Gas owned by Tokyo Gas shall be delivered to Gatherer by Producer, but shall be gathered by Gatherer pursuant to the Tokyo Gas Gathering Agreement. As between Producer and Gatherer, Producer shall be solely responsible for imbalances, penalties, cash-out payments, or other consequences of any failure to submit timely and proper nominations in accordance with the requirements of the Transporter or the failure to deliver or receive quantities of the Subject Gas in accordance with said nominations.

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6.3    Gatherer and Producer shall designate a dispatcher(s) who shall be continuously on call for nomination purposes, and shall notify each other in writing of such dispatcher(s) and their telephone number(s).

6.4    Producer’s dispatcher shall notify Gatherer’s dispatcher(s) in advance of any anticipated decrease in delivery rate below the daily nominated quantity. Producer’s dispatcher(s) must obtain the prior written approval from Gatherer’s dispatcher(s) for any delivery rate in excess of the daily quantity rate. Gatherer’s dispatcher(s) shall notify Producer’s dispatcher(s) of any anticipated inability to receive the Gas at a delivery rate less than (a) the daily nominated quantity rate; or (b) a previously orally authorized delivery rate in excess of the daily nominated quantity rate.

6.5    The quantity of Gas delivered by Producer at each Receipt Point hereunder during a Month shall be determined in accordance with the allocation procedures set forth in Section 10 below.

6.6    Producer and Gatherer shall conduct semi-annual technical meetings at which Producer shall provide Gatherer with estimated monthly volume forecasts, drilling and development plans for the next twelve (12) months, and discuss other operational matters, and at which Gatherer shall provide Producer Gatherer’s projected maintenance and system outage schedules, Gathering System pressures and operating constraints, and system balances for the next twelve (12) months, and discuss other operational matters.

7.    Quality

7.1    Gatherer shall not be obligated to receive, gather, or redeliver (as the case may be) the Subject Gas delivered by or on behalf of Producer hereunder that fails to meet the quality specifications of (i) the Transporter at any of the Delivery Point(s), except for quality specifications relating to hydration and CO2 content of the Subject Gas that are contemplated to be satisfied by virtue of Gatherer’s provision of certain dehydration and treating services at its existing treating facility as more particularly described in Exhibit C attached hereto, or (ii) the following specifications:

a.    The Subject Gas must be commercial in quality and free from any foreign materials such as dirt, dust, iron particles, crude oil, dark condensate, free water, and other impurities; and substances which may be injurious to pipelines or which may interfere with the gathering, processing, transmission, or commercial utilization of said Subject Gas;

b.    The Subject Gas delivered hereunder shall not exceed a temperature of one hundred twenty (120) degrees Fahrenheit, nor have a

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hydrocarbon dewpoint below forty (40) degrees Fahrenheit, at the Receipt Point(s);

c.    The Subject Gas delivered hereunder shall not contain more than:

(i)    One-fourth grain of hydrogen sulfide, or five grains of total sulfur, or one grain mercaptan per one hundred (100) cubic feet;

(ii)    one part per million by volume of oxygen; or

(iii)    two percent by volume of nitrogen.

d.    No diluents such as carbon dioxide, air, or nitrogen shall be added to the Subject Gas;

e.    The Subject Gas shall contain no carbon monoxide, halogens, or unsaturated hydrocarbons, and no more than 0.1 parts per million of hydrogen; and

f.    The Subject Gas shall have a total heating value of not less than 950 Btus nor more than 1050 Btus per cubic foot and 2 GPM of ethane and heavier hydrocarbons.

In the event of any conflict as between specifications of a Transporter and those above, the most stringent or restrictive specifications shall be applicable to the Subject Gas proffered under this Agreement. With respect to the “no water” or “hydrocarbons in liquid form” specification, Producer agrees to operate its facilities in a prudent manner so that no water or hydrocarbons in liquid form enters the Gathering System. In the event Gatherer receives liquid water or hydrocarbons from Producer at any Delivery Point, in addition to any adjustments to gas measurement that may be necessary to accurately reflect the quantity of the Subject Gas delivered by Producer to Gatherer at such Delivery Point, Gatherer shall have the right, if such receipts of liquid water or hydrocarbons have not ceased within seven (7) Days after Gatherer’s written notice to Producer, to cease taking deliveries of the Subject gas at such Delivery Point until such time as Producer rectifies the situation.

7.2    If any of the Subject Gas delivered by Producer hereunder should fail to meet the quality specifications set forth in Section 7.1, Gatherer may elect to either (i) accept and gather such Subject Gas, (ii) accept, but treat and/or condition such Subject Gas prior to gathering at an additional cost, or (iii) refuse to accept such Subject Gas. The acceptance of the Subject Gas not meeting the quality specifications set forth in Section 7.1 shall not be deemed a waiver of Gatherer’s right to reject such Subject Gas at any later time, and Gatherer shall be entitled, at an

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y time and from time to time, to decline to accept proffered deliveries of the Subject Gas not meeting the quality specifications set forth herein.

7.3     If Gatherer elects to accept but treat and/or condition the nonconforming the Subject Gas prior to gathering, Gatherer shall advise Producer of such election and associated fees and costs to be charged by Gatherer. Producer shall then have a maximum of thirty (30) days to advise Gatherer if it will treat and/or condition such non-conforming Subject Gas and the cost associated with such treatment. If Producer does not elect to treat and/or condition such nonconforming Subject Gas or fails to make such election within the specified time period, then Gatherer shall have the right to (i) proceed with gathering such nonconforming Subject Gas and Producer shall pay to Gatherer all associated fees and costs charged by Gatherer in connection with such actions, or (ii) reject and release such non-conforming Subject Gas from the terms of this Agreement.

7.4.    If there is an enactment of, or change in, any law after the Effective Date that, in Gatherer’s reasonable determination, results in a governmental authority requiring Gatherer or Producer to hold or acquire emission allowances or their equivalent related to the carbon dioxide content or emissions or the greenhouse gas content or emissions attributable to Gas and/or the gathering and/or processing of such Gas (collectively, “Producer’s GHG Emissions”), then Gatherer will notify Producer of such enactment of, or change in, such law. Thereafter, Producer shall use commercially reasonable efforts to provide any required emissions allowances or their equivalents to Gatherer in a timely manner. If Producer fails to provide such emission allowances or their equivalents and Gatherer incurs expenses to acquire such allowances or their equivalents in the marketplace, or incurs any out-of-pocket costs or expenses for disposal or treating of carbon dioxide, or otherwise, or if any other additional economic burden is placed on Gatherer in connection with or related to Producer’s GHG Emissions, including but not limited to any tax, assessment, or other cost or expense (collectively, “Emissions Charges”), such Emissions Charges shall be fully the responsibility of Producer. Should Gatherer incur any such Emissions Charges, Producer shall reimburse Gatherer for the same within thirty (30) Days of receipt of an invoice along with reasonable supporting documentation. If carbon dioxide is sold by Gatherer on behalf of Producer, then the proceeds, net of Emissions Charges, taxes, and costs and expenses of such sale, shall be paid to Producer or deducted from amounts owed by Producer pursuant to this Agreement. Notwithstanding the foregoing, should any such enactment of, or change in, law require Gatherer to construct new facilities or to modify any part of the Gathering System or the Plant under this Section 7.4, the Parties shall negotiate in good faith and use commercially reasonable efforts to agree on the most cost effective method of constructing or modifying such facilities.

8.    Tests

8.1    Producer and Gatherer do hereby agree as follows:

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a.    Gatherer shall procure or cause to be procured a sample of the Subject Gas at each Receipt Point and Delivery Point, respectively, and analyze the samples by chromatographic analysis to determine the Component content (mole percent), specific gravity, and the Btu content thereof.

b.    Tests provided for in Subparagraphs (a) of this Section 8.1 shall be made by Gatherer using its own equipment or by an independent testing service. Samples will be taken at each Gathering System Delivery Point according to the monthly average daily flow capabilities of such Gathering System Delivery Point as follows: Gathering System Delivery Point(s) that average 5,000 Mcf per day and higher shall be sampled monthly; Gathering System Delivery Points that average between 4,999 Mcf and 1,000 Mcf per day shall be sampled quarterly; and Gathering System Points of Delivery that average below 1,000 Mcf per day shall be tested semi-annually or more often as Gatherer deems necessary. All such tests shall be made in accordance with approved engineering practices. Representatives of Producer shall be entitled to witness such tests, and Producer shall give advance written notice to Gatherer in the event that it exercises such right.

8.2    Physical constants required for making calculations hereunder shall be taken from the Gas Processors Association Physical Constants Publication No. 2145-03 (as amended from time to time). Physical constants for the hexanes and heavier hydrocarbons portion of hydrocarbon mixtures shall be assumed to be the same as the physical constants for hexane. The heat content per gallon of each liquid hydrocarbon Component shall be determined by multiplying the cubic feet per gallon of such liquid hydrocarbon Component by the heat content per cubic foot thereof.

9.    Measurement and Meter Testing

9.1    The unit of volume for measurement of Gas delivered hereunder shall be one thousand (1,000) cubic feet of Gas (or MCF) at a base temperature of 60 degrees Fahrenheit and at an absolute pressure of 14.65 psia and saturated with water vapor. All fundamental constants, observations, records, and procedures involved in determining the quantity of Gas delivered hereunder shall be in accordance with the standards prescribed in Report Nos. 3 and 8, of the American Gas Association, as amended or supplemented from time to time, respectively. It is agreed that for the purpose of measurement and computations hereunder, the atmospheric pressure shall be assumed to be 14.65 psia regardless of the atmospheric pressure at which the Gas is measured and that the Gas obeys the Ideal Gas Laws as to variations of volume with pressure and specific gravity, including the deviation from Boyle’s law, and shall all be made by Gatherer in accordance with applicable rules, regulations, and orders. It is also agreed that

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Gatherer may apply a uniform correction factor for water vapor if Gatherer deems it necessary in its sole and absolute discretion.

9.2    Gatherer shall install, maintain, and operate, or cause to be maintained and operated, a measuring station located at each Receipt Point and Delivery Point. Said measuring station(s) shall be so equipped with orifice meters, recording gauges, or other types of meter or meters of standard make and design commonly acceptable in the industry, and of suitable size and design, as to accomplish the accurate measurement of the Subject Gas delivered hereunder. The changing and integration of the charts (if utilized for measurement purposes hereunder) and calibrating and adjusting of meters shall be done by Gatherer. Gatherer shall have the right to utilize electronic gas measuring equipment should it so desire.

9.3    Producer may, at its option and expense, install check meters for checking Gatherer’s metering equipment at each Receipt Point; and the same shall be so installed as not to interfere with the operation of the Gathering System.

9.4    The temperature of the Subject Gas flowing through the meter shall be determined by the continuous use of a recording thermometer or device installed by Gatherer, so that it will properly record the temperature of the Subject Gas flowing through the meter.

9.5    The specific gravity of the Subject Gas flowing through the meter shall be determined by methods commonly accepted in the industry. Specific gravities so determined will be used in calculating Subject Gas deliveries until the next specific gravity test is made.

9.6    Each Party shall have the right to be present at the time of any installation, reading, sampling, cleaning, changing, repair, inspection, testing, calibration, or adjustment done in connection with the other Party’s measuring equipment used in measuring deliveries hereunder. The records from such measuring equipment shall remain the property of their owner, but upon request, each will submit to the other its records and charts, together with calculations therefrom subject to return within thirty (30) days after receipt thereof. If meters utilizing charts are used to measure the Subject Gas hereunder, then the charts shall be kept on file for a period of two (2) years, or such longer period as may be required by law. In addition, any other measurement data shall also be kept for the same time period. Each Party, during the first production month, and after that at least semi-annually, or more often if necessary, shall calibrate the meters and instruments installed by it or cause the same to be calibrated. Gatherer shall give Producer ten (10) days notice in advance of such tests so that the latter may, at its election, be present in person or by its representative to observe adjustments, if any are made.

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9.7    If the metering equipment is found to be inaccurate by two percent (2%) or more, registration thereof and any payment based upon such registration shall be corrected at the rate of such inaccuracy for any period of inaccuracy which is definitely known or agreed upon, or if not known or agreed upon, then for a period extending back one-half of the time elapsed since the last day of the calibration. Unless conclusively determined that Gatherer’s measurement equipment is inaccurate by two percent (2%) or more, Gatherer’s measurement shall be deemed to be correct for all purposes hereunder, and no adjustment shall be made to the previous volumes. Following any test, any metering equipment found to be inaccurate to any degree shall be adjusted immediately to measure accurately. If for any reason any meter is out of service or out of repair so that the quantity of the Subject Gas delivered through such meter cannot be ascertained or computed from the readings thereof, the quantity of the Subject Gas so delivered during such period shall be estimated and agreed upon by the Parties upon the basis of the best available data using the first of the following methods which is feasible:

a.    By using the registration of any check measuring equipment of Producer, if installed and registering accurately;

b.    By correcting the error if the percentage of error is ascertainable by calibration, test, or mathematical calculation; or

c. By estimating the quantity of deliveries during preceding periods under similar conditions when the meter was registering accurately.

9.8    If Producer shall notify Gatherer, or if Gatherer shall notify Producer, at any time that a special test of any Receipt Point meter is desired, the Parties shall cooperate to secure an immediate verification of the accuracy of such meter and joint observation of any adjustments. All tests of Gatherer’s measuring equipment at any Receipt Point shall be made at Gatherer’s expense, except that Producer shall bear the expense of tests made at its request if the inaccuracy found is less than two percent (2%). Expense as used in this Section 9.8 shall be limited to actual out-of-pocket costs of Gatherer as the result of testing and shall not include any costs incurred by Producer as the result of witnessing said testing.

9.9    If during any month less than 1,000 MCF of Gas is delivered to a Receipt Point (except for reasons of Force Majeure), then Gatherer shall charge a meter fee applicable to any such Receipt Point equal to (***). Such fee shall be invoiced to Producer and payable thirty (30) days after receipt by Producer of such invoice.

9.10    The Parties recognize and acknowledge that technological advances may occur over the term of this Agreement which may render certain measurement devices obsolete, or less accurate, or less efficient than that which may be available. In such event, Gatherer may, with Producer’s approval, substitute or utilize such

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available measurement equipment in lieu of any measurement equipment described above in this Section 9.

9.11    If for any reason the Subject Gas is delivered to Gatherer at a Receipt Point with pulsations that affect the accuracy of the measurement, Producer shall be responsible for installing necessary pulsation dampeners, or other devices, to eliminate or reduce the pulsations to a reasonably acceptable level determined by Gatherer.

10.    Allocation of Gains, Fuel and Loss

10.1    Gatherer shall use general industry care in transporting the Subject Gas from the Receipt Point(s) to the Delivery Point(s) for Producer’s account or sale. However, the Parties understand and agree that certain volumetric gains and losses in the Subject Gas will occur and shall be shared by and among Producer and other third parties whose gas is transported by Gatherer, in the proportion that the gas of each Person who delivers gas into the Gathering System bears to the total gas received at the respective receipt point. In determining the quantity of the Subject Gas delivered by Producer at each Receipt Point hereunder during a month, Gatherer shall allocate to Producer at each such Receipt Point a quantity of gas equal to (a) a percentage of the total quantities (expressed in MMBtus) reported for such Month by the Transporter at the Delivery Point(s) (the “Total Delivered Quantities”) equal to 100% of such Total Delivered Quantities times a fraction, the numerator of which is the number of MMBtus of the Subject Gas delivered by Producer during such Month at said Receipt Point, and the denominator of which is the number of MMBtus of all gas delivered into the Gathering System from all receipt points, minus (b) Producer’s applicable Fuel and Loss. In making the determinations under this Section 10, Gatherer may rely on, and shall be fully protected in relying on, any determination, report or statement received by Gatherer from any operator of a well regarding the number of MMBtus delivered from such well into the Gathering System at any receipt point on the Gathering System.

10.2    Producer’s pro rata share of such Fuel and Loss shall equal the product of the total Fuel and Loss utilized, consumed or incurred by the Gathering System, multiplied by a fraction, the numerator of which is Producer’s MMBtus of the Subject Gas metered into the Gathering System at the Receipt Point(s) and the denominator of which is the total number of MMBtus of gas metered into the Gathering System upstream of all receipt points.

10.3    Electrical Power shall be utilized in the operation of the Gathering System (including Electrical Power used for dehydration, compression, conditioning, blending, treating, or recompression), and Producer’s pro rata share shall equal the product of the total dollar amount paid for such Electrical Power multiplied by a fraction, the numerator of which is the number of Producer’s MMBtus of the Subject Gas metered into the Gathering System upstream of the Receipt

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Point(s) and the denominator of which is the total number of MMBtus of gas metered into the Gathering System upstream of all receipt points, to be invoiced to Producer and paid to Gatherer in accordance with Section 12 below. Producer reserves the right to participate in the selection of Electrical Power suppliers but Gatherer is entitled to make the final decisions on such selections.

11.    Fees

11.1    Producer shall pay to Gatherer a rate equal to (***) of the Subject Gas received by Gatherer and metered at the Receipt Points, subject to adjustment as provided in Section 11.3 (such rate, as so adjusted, the “Gathering Fee”). In addition to the Gathering Fee, Producer shall pay on each MCF of the Subject Gas received by Gatherer and metered at the Receipt Points an additional rate equal to (***) of the published (***) Index (as published on an MMBtu basis).

11.2    Producer shall pay to Gatherer (***) per MCF of Lift Gas redelivered to Producer pursuant to Lift Gas systems in existence as of the Effective Date, subject to adjustment as provided in Section 11.3 (such rate, as so adjusted, the "Lift Gas Fee").

11.3    On each Escalation Date, the Gathering Fee and the Lift Gas Fee will increase by a percentage equal to the CPI Adjustment.

11.4    Subject to Section 11.5, Gatherer shall have the Exclusive Right to provide Producer's gas lift needs for the remaining Term of the Agreement. As used herein, the term “Exclusive Right" is defined to mean that (i) Gatherer shall be the exclusive provider of gas lift services to Producer at the existing and any future points delivered into Producer's existing and future gas lift systems, and (ii) Producer shall negotiate with no other party and deal exclusively with Gatherer to potentially provide any alternative gas lift method which could eliminate or materially alter the then existing manner in which Gatherer supplies lift gas to Producer at existing and future wells. If Gatherer elects (other than as a result of force majeure) to discontinue deliveries of lift gas or fails to provide lift gas at a pressure of 950 psig or higher for a period of thirty (30) consecutive days or longer, Producer shall have the option, exercised solely at its discretion, by providing written notice to Gatherer to terminate Gatherer’s Exclusive Right with respect to the affected points of delivery.

11.5.     If Producer has Lift Gas needs that require the construction of a new gas lift system within the Contract Area, Producer shall notify Gatherer with any proposed reasonable supporting documentation (including the location of any existing or proposed well(s)) sufficient for Gatherer to evaluate whether building of a new gas lift system to any existing or proposed well would be economic pursuant to the fee structure set forth in this Agreement. Gatherer, in its sole and absolute discretion, may decline to construct any new gas lift system. Within sixty (60) Days after receiving notice (or, if later, reasonable supporting documentation) from

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Producer, Gatherer shall notify Producer whether or not it elects to construct such new gas lift system pursuant to the fee structure set forth in this Agreement. If Gatherer elects to construct the new gas lift system, such construction shall be completed and functioning as soon as reasonably practicable subject to force majeure affecting Gatherer’s performance, after receiving notice (or, if later, reasonable supporting documentation) from Producer (the “Gas Lift Construction Period”). In the event either Gatherer elects not to construct the new gas lift system or elects to build such construction, but it is not completed and functioning within the Gas Lift Construction Period, Producer shall have the right to cause the proposed Lift Gas needs to be provided as it sees fit, by a third party or otherwise.

11.6    Sections 11.4 and 11.5 are not intended to hinder Producer from alternative non gas lift methods (including, but not limited to, plungers or other similar lifting technologies) at any individual well (including each such well for which there is no gas lift pipeline connection as of the date hereof), where such lift gas being provided or to be provided, as applicable, by Gatherer is not or will not be adequate at such particular well to provide Producer's lift requirements. Producer shall retain sole discretion in the deployment of these alternative non gas lift techniques; provided in the event that Producer employs such artificial non gas lift techniques on a well, it will notify Gatherer within a commercially reasonable time frame.

12.    Accounting, Payments and Credit Assurances

12.1    Producer shall furnish to Gatherer on or before the first day of each month a report or statement disclosing information necessary to enable Gatherer to determine the percentage of gas delivered at each Receipt Point that is owned by Producer and the percentage of gas delivered at each Receipt Point that is owned by any other working interest owner for which Producer delivered gas to the Gathering System (and each such working interest owner’s respective percentage of such gas) related to the preceding month. Gatherer shall furnish to Producer on or before the twenty-fifth (25th) day of each month a report or statement disclosing information necessary to enable Producer to make reasonable and accurate statistical and accounting entries upon its books concerning all phases of this Agreement related to the preceding month, including any statement of the Subject Gas delivered for Producer’s account to its Transporter, the total volume of the Subject Gas in MCF and in MMBtu measured at the Receipt Point(s), Producer’s pro rata share of Fuel and Loss and the cost billed to Gatherer for Electrical Power, if any, and the amounts due Gatherer for the services provided hereunder. Producer shall remit the amounts due Gatherer with respect to the Subject Gas within thirty (30) days after the receipt of Gatherer’s statement. PRODUCER SHALL INDEMNIFY AND HOLD GATHERER HARMLESS FROM ANY AND ALL CHARGES, PENALTIES, COSTS AND EXPENSES OF WHATEVER KIND OR NATURE ARISING FROM PRODUCER’S FAILURE TO PAY SUCH PAYMENTS, INCLUDING COSTS AND EXPENSES OF ANY LITIGATION AND REASONABLE ATTORNEYS’ FEES ASSOCIATED THEREWITH. Unpaid amounts due with

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respect to Subject Gas shall accrue interest at the lesser of a rate equal to one and one half percent (1.5%) per month or the maximum rate permitted by law, until the balance is paid in full.

12.2    Each Party shall have the right during reasonable hours to examine books, records, charts, and original test data of the other Party to the extent necessary to verify the accuracy of any statement, charge, credit, computation, test, or delivery made pursuant to any provision hereof. If any such examination reveals any inaccuracy in any such statement, charge, credit, computation, test, or delivery, the necessary adjustment shall be promptly made without interest or penalty. Neither Party will have any right to recoup or recover prior overpayments or under payments that result from error that occur in spite of good faith performance if the amounts involved do not exceed fifty dollars ($50.00) per month per Receipt Point.

12.3    Producer shall be responsible for the payment of all royalties due on the Gas. Producer shall indemnify and hold Gatherer harmless from any and all claims, actions, causes of action, damages, liability, or obligations arising out of or in any way related to the payment of the lessor’s royalty or any other burden or encumbrance affecting the Gas.

12.4    Notwithstanding any change in ownership of Producer’s properties, Gatherer shall never be required to make payments or to give notices required under the provisions of this agreement to more than one party.

12.5    All accounting records and documents directly related to this Agreement prepared by any Party shall be retained for a period of not less than two years following the end of the calendar year of their origination. The Parties further agree that all matters relating to the accounting hereunder for any calendar year shall be considered correct and not subject to further audit or legal challenge after two years following the end of the calendar year.

12.6    Producer creditworthiness requirements shall be substantially similar to those requirements set forth below:

a. Producer will be deemed creditworthy: (i) during a period in which Producer does not have long-term secured debt securities rated by S&P and Moody’s, then if according to the most recent of (y) Producer’s audited annual financial statements, or (z) Producer’s quarterly financial statements, (A) its current ratio (dividing current assets (which shall include available borrowings under its credit facility and undrawn equity committed by its equity holders) by current liabilities) is (***) or higher and (B) its leverage ratio as determined using the methodology required by its bank group is at least (***) below its then-current bank group covenant but in no event greater than (***); or (ii) otherwise, if its long-term unsecured

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debt securities are rated at least BB- by Standard & Poor's Corporation ("S&P") and at least Ba3 by Moody's Investor Service ("Moody's"); provided, however, that if the Producer's rating is at BB- or Ba3 and the short-term or long-term outlook is negative, Gatherer may require further analysis. Producer shall provide its most recent audited financial statements on the Effective Date and, in the event Producer does not have long-term unsecured debt securities rated by S&P and Moody’s, then Producer must also provide Gatherer audited annual financial statements on an annual basis and unaudited quarterly financial statements on a quarterly basis.

b. If Producer does not meet the criteria described above, then Producer may request that Gatherer evaluate its creditworthiness based upon the level of service requested relative to the Producer's current and future ability to meet its obligations. Further, if Producer's creditworthiness does not meet any of the foregoing criteria, Producer will be considered creditworthy if Producer maintains and delivers to Gatherer an irrevocable guaranty of payment in form acceptable to Gatherer, or an irrevocable letter of credit from a financial institution rated at least A- by S&P or at least A3 by Moody's, in a form acceptable to Gatherer, in either case of the guaranty or the letter of credit in an amount satisfactory to Gatherer, which will be equal to the total amounts invoiced to Producer by Gatherer in the immediately preceding two (2) Months. The obligation to maintain such credit assurance shall extend until such time as Producer is deemed creditworthy as defined herein. Producer shall provide the guaranty or the letter of credit within twenty (20) days of written notice by Gatherer that such financial assurance is required.

c. The creditworthiness requirements set forth in this Section 12.6 shall apply to any permitted assignment (in whole or in part), and to any permitted permanent release, as applicable, of this Agreement. Gatherer shall apply consistent evaluation practices to all similarly situated producers to determine Producer’s financial ability to perform the payment obligations due to Gatherer

13.    Warranty

13.1    PRODUCER warrants the title to all the Subject Gas owned by Producer and all components thereof which shall be delivered by Producer to Gatherer hereunder, the right to enter into this Agreement with reference to such Subject Gas, and that such Subject Gas owned by Producer is free from all liens and adverse claims; and AGREES, IF NOTIFIED THEREOF BY GATHERER, TO INDEMNIFY, DEFEND AND HOLD

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GATHERER HARMLESS FROM AND AGAINST ANY AND ALL SUITS, ACTIONS, LOSSES, DEBTS, ACCOUNTS, DAMAGES, COSTS AND EXPENSES ARISING FROM OR OUT OF ANY ADVERSE CLAIM AS TO PRODUCER’S TITLE, INCLUDING BUT NOT LIMITED TO, ANY ADVERSE CLAIMS BROUGHT BY OR THROUGH A MINERAL INTEREST OR ROYALTY OWNER, TO OR AGAINST THE SUBJECT GAS OWNED BY PRODUCER. Producer agrees to make settlement for all royalties, overriding royalty interests, and/or production payments due and payable on the Subject Gas delivered to Gatherer hereunder, any Components of the Subject Gas extracted or saved therefrom, and the sale and disposition of the Subject Gas and any Components thereof, all in accordance with the terms of the leases, interests and/or agreements (including applicable instruments of title) from which the Subject Gas delivered to Gatherer hereunder is produced, and all amendments thereto.

13.2    Producer also represents and warrants that it has full authority to receive payment for the sum of all of the Subject Gas delivered hereunder.

14.    Taxes

14.1    Producer shall pay or cause to be paid all production, severance and ad valorem taxes, assessments, and other charges levied or assessed against the Gas gathered hereunder, and all taxes and statutory charges levied or assessed against any of Producer’s properties, facilities, or operations. Producer shall reimburse Gatherer to the extent of any severance or other such taxes paid by Gatherer on behalf of Producer.

14.2    Gatherer shall pay all taxes and statutory charges levied or assessed against the Gathering System and operations concerning such system.

15.    Indemnity and Damages

15.1    As between the Parties, and as to liability, if any, accruing to either Party or to any third party, Producer shall be solely liable for and in control and possession of, and bear the risk of loss with respect to, the Gas deliverable hereunder until the Gas is delivered to Gatherer at the Receipt Point(s). Gatherer shall be solely liable for and in control and possession of, and bear the risk of loss with respect to, the Gas after the Gas is delivered to Gatherer at the Receipt Point(s) hereunder until the Subject Gas is delivered to Producer or to the Transporter on Producer’s behalf at the Delivery Point(s), whereupon Producer shall again be solely liable for the Subject Gas and in control and possession thereof and bear the risk of loss of the Subject Gas delivered to Transporter. If Lift Gas is redelivered to Producer as provided herein, then, in that event, Gatherer shall be solely liable for and in control and possession of such Lift Gas from the time such Lift Gas exits the Gathering System until redelivered to Producer, whereupon Producer shall again be in control and possession and bear the risk of loss of such Lift Gas.

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15.2    PRODUCER SHALL BE AFFORDED ACCESS TO GATHERER’S PROPERTY AND THE FACILITIES TO THE EXTENT NECESSARY TO CARRY OUT ITS RIGHTS AND OBLIGATIONS UNDER THIS AGREEMENT, AND PRODUCER SHALL FULLY OBSERVE AND COMPLY WITH ALL OF GATHERER’S SAFETY PRACTICES AND PROCEDURES WHILE ON THE PREMISES. PRODUCER HEREBY AGREES TO INDEMNIFY, HOLD HARMLESS, PROTECT, DEFEND, AND DISCHARGE GATHERER AND ITS AFFILIATED COMPANIES, PARTNERS, SUCCESSORS, ASSIGNS, OFFICERS, DIRECTORS, MANAGERS, SHAREHOLDERS, MEMBERS, EMPLOYEES AND AGENTS FOR, FROM AND AGAINST ANY AND ALL JUDGMENTS, EXECUTIONS, CAUSES OF ACTION, DEMANDS, RIGHTS, SUITS, DEBTS AND SUMS OF MONEY, ACCOUNTINGS, DUES, PENALTIES, FINES, CLAIMS (INCLUDING, WITHOUT LIMITATION, CLAIMS FOR CONTRIBUTION), LIABILITIES, LOSSES, COSTS, DAMAGES AND EXPENSES (INCLUDING COURT COSTS, REASONABLE COSTS OF INVESTIGATION, DEFENSE AND ATTORNEY’S FEES) FOR THE INJURY TO OR DEATH OF ANY PERSON (INCLUDING, WITHOUT LIMITATION, EACH OF PRODUCER’S AND GATHERER’S EMPLOYEES, AGENTS AND CONTRACTORS) OR PROPERTY DAMAGE OF ANY NATURE, KIND OR DESCRIPTION OR ANY OTHER CLAIM OF ANY NATURE, KIND OR DESCRIPTION BROUGHT BY ANY PERSON, WHETHER LEGAL OR EQUITABLE, WHICH ARISES OUT OF OR RESULTS FROM (I) PRODUCER’S OWNERSHIP AND CONTROL OF (a) THE GAS PRIOR TO THE TIME THAT THE GAS PASSES THROUGH THE GATHERING SYSTEM RECEIPT POINT(S) AND AFTER THE GAS PASSES THROUGH THE DELIVERY POINT(S) AND (b) THE LIFT GAS AFTER THE LIFT GAS HAS BEEN REDELIVERED TO PRODUCER AND PRIOR TO THE TIME THAT GAS, INCLUDING SUCH LIFT GAS, PASSES THROUGH THE RECEIPT POINT, (II) PRODUCER’S OWNERSHIP AND OPERATION (OR ANY OPERATION ON BEHALF OF PRODUCER) OF THE WELLS LOCATED WITHIN THE CONTRACT AREA AND ANY FACILITIES OR EQUIPMENT INSTALLED OR MAINTAINED BY PRODUCER OR ITS OPERATORS UPSTREAM OF THE GATHERING SYSTEM RECEIPT POINT, REGARDLESS OF WHETHER SUCH WAS REQUIRED BY THE TERMS OF THIS AGREEMENT, (III) ANY ACCESS TO GATHERER’S PROPERTY BY (OR ANY DELIVERY OF GATHERER’S RECORDS OR CHARTS TO) PRODUCER OR ITS REPRESENTATIVES, EMPLOYEES, AGENTS OR CONTRACTORS, (IV) PRODUCER’S BREACH OF THIS AGREEMENT, OR (V) ANY VIOLATION OF THE LAW BY PRODUCER, IN EACH CASE REGARDLESS OF ANY SOLE, CONCURRENT OR COMPARATIVE NEGLIGENCE OR STRICT LIABILITY OF GATHERER OR ANY OF THE PERSONS INDEMNIFIED BY PRODUCER UNDER THE FOREGOING PROVISIONS.

GATHERER HEREBY AGREES TO INDEMNIFY, HOLD HARMLESS, PROTECT, DEFEND AND DISCHARGE PRODUCER AND ITS AFFILIATED COMPANIES, PARTNERS, SUCCESSORS, ASSIGNS, OFFICERS, DIRECTORS,

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SHAREHOLDERS, EMPLOYEES AND AGENTS FOR, FROM AND AGAINST ANY AND ALL JUDGMENTS, EXECUTIONS, CAUSES OF ACTION, DEMANDS, RIGHTS, SUITS, DEBTS AND SUMS OF MONEY, ACCOUNTINGS, DUES, PENALTIES, FINES, CLAIMS (INCLUDING, WITHOUT LIMITATION, CLAIMS FOR CONTRIBUTION), LIABILITIES, LOSSES, COSTS, DAMAGES AND EXPENSES (INCLUDING COURT COSTS, REASONABLE COSTS OF INVESTIGATION, DEFENSE AND ATTORNEY’S FEES) FOR THE INJURY TO OR DEATH OF ANY PERSON (INCLUDING, WITHOUT LIMITATION, EACH OF PRODUCER’S AND GATHERER’S EMPLOYEES, AGENTS AND CONTRACTORS) OR PROPERTY DAMAGE OF ANY NATURE, KIND OR DESCRIPTION OR ANY OTHER CLAIM OF ANY NATURE, KIND OR DESCRIPTION BROUGHT BY ANY PERSON, WHETHER LEGAL OR EQUITABLE, WHICH ARISES OUT OF OR RESULTS FROM (I) GATHERER’S CONTROL OF (a) THE GAS AFTER THE GAS PASSES THROUGH THE GATHERING SYSTEM RECEIPT POINTS TO THE TIME THAT THE GAS PASSES THROUGH THE DELIVERY POINT(S) AND (b) THE LIFT GAS FROM THE TIME SUCH LIFT GAS EXITS THE GATHERING SYSTEM UNTIL SUCH LIFT GAS IS REDELIVERED TO PRODUCER, (II) GATHERER’S OWNERSHIP AND OPERATION OF THE GATHERING SYSTEM, (III) GATHERER’S BREACH OF THIS AGREEMENT, OR (IV) ANY VIOLATION OF THE LAW BY GATHERER, IN EACH CASE REGARDLESS OF ANY SOLE, CONCURRENT OR COMPARATIVE NEGLIGENCE OR STRICT LIABILITY OF PRODUCER OR ANY OF THE PERSONS INDEMNIFIED BY GATHERER UNDER THE FOREGOING PROVISIONS. THE INDEMNIFICATION RIGHTS HEREIN SHALL BE CUMULATIVE OF, AND IN ADDITION TO, ANY AND ALL OTHER RIGHTS, REMEDIES OR RECOURSE OF THE PARTIES AND SHALL SURVIVE ANY EXPIRATION OR TERMINATION OF THIS AGREEMENT. TO THE EXTENT AND ONLY TO THE EXTENT THE FOREGOING INDEMNIFICATION RIGHTS ARE BY LAW, EITHER INAPPLICABLE OR NOT ENFORCEABLE, PRODUCER AND GATHERER SHALL EACH BE RESPONSIBLE FOR THE RESULTS OF ITS OWN ACTIONS AND FOR THE ACTIONS OF THOSE PERSONS AND ENTITIES OVER WHICH IT EXERCISES CONTROL.

15.3    NOTWITHSTANDING ANYTHING CONTAINED IN THIS SECTION 15 OR ELSEWHERE IN THIS AGREEMENT TO THE CONTRARY, NEITHER PARTY SHALL BE LIABLE FOR ANY PUNITIVE, EXEMPLARY, CONSEQUENTIAL, INCIDENTAL, SPECIAL, OR INDIRECT DAMAGES, LOST PROFITS, OR OTHER BUSINESS INTERRUPTION DAMAGES, IN TORT OR CONTRACT, IN CONNECTION WITH OR OTHERWISE ARISING OUT OF THIS AGREEMENT, EXCEPT TO THE EXTENT SUCH DAMAGES HAVE BEEN AWARDED TO A THIRD PARTY WHO IS NOT AN AFFILIATE OF A PARTY AND ARE SUBJECT TO ALLOCATION BETWEEN OR AMONG THE PARTIES PURSUANT TO ANY TERMS OF THIS AGREEMENT.

16.    Force Majeure

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In the event any Party is rendered unable, either wholly or in part, by force majeure to carry out its obligations under this Agreement, other than the obligation to make payments due hereunder, it is agreed that on such Party giving notice and full particulars of such inability by telephone and in writing to the other Parties as soon as possible after the occurrence of the cause relied on, then the obligations of the Party giving such notice, so far as they are affected by such force majeure, shall be suspended during the continuance of any inability so caused, but for no longer period, and such cause shall, as far as possible, be remedied with all reasonable dispatch by the Party claiming the force majeure. The term "force majeure" as employed herein shall mean any act or event which wholly or partially prevents or delays the performance of obligations arising under this Agreement if such act or event is not reasonably within the control of and not caused by the fault or negligence of the Party claiming force majeure and which by the exercise of due diligence such Party is unable to prevent or overcome, including, without limitation, by the following enumeration: acts of God; strikes; lockouts; or other industrial disturbances; acts of the public enemy; wars; blockades; insurrections; riots; epidemics; landslides; lightning; earthquakes; fires; storms; floods; washouts; arrests and restraints of governments and people; civil disturbances; explosion, breakage, or accidents to machinery, plant facilities, or lines of pipe; the necessity for making repairs to or alterations of machinery, plant facilities, or lines of pipe; freezing of wells or lines of pipe; partial or entire failure of wells; and the inability of either Producer or Gatherer to acquire, or the delays on the part of either Producer or Gatherer in acquiring, at reasonable cost and after the exercise of reasonable diligence: (a) any servitude, rights-of-way grants, permits, or licenses; (b) any materials or supplies for the construction or maintenance of facilities; and (c) any permits or permissions from any governmental agency if such are required. It is understood and agreed that the settlement of strikes or lockouts shall be entirely within the discretion of the Party having the difficulty and that the above requirements that any force majeure shall be remedied with all reasonable dispatch shall not require the settlement of strikes or lockouts by acceding to the demands of the opposing party when such course is inadvisable in the sole discretion of the Party having the difficulty. Notwithstanding anything contained herein to the contrary, in the event that Gatherer is unable to carry out its obligations under this Agreement due to a force majeure, then during the time period of such force majeure, Producer may dispose of the Subject Gas as it sees fit.

17.    Unprofitable Operations and Rights of Termination

17.1    If, in the reasonable opinion of Gatherer, (a) the gathering of the Subject Gas from any well within the Contract Area or any Receipt Point(s), or (b) the delivery of the Subject Gas to any Delivery Point(s), is or becomes uneconomical due to its volume, quality, government regulations, or for any other cause, Gatherer shall not be obligated to gather and may cease gathering such Subject Gas so long as such condition exists. Gatherer agrees that in its determination of uneconomical gathering, the same criteria shall be used for the Subject Gas as for all other gas being gathered through the Gathering System. In the event that Gatherer refuses to gather the Subject Gas, Producer may dispose of the Subject Gas not gathered

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as it sees fit; provided that Gatherer at any time thereafter shall have the right to gather all of the Subject Gas refused, if refused for reason or reasons resulting from an act of Producer or lack of action on the part of Producer, conditioned upon Gatherer giving Producer at least two (2) months’ notice of its election to so do. Notwithstanding anything contained herein to the contrary, in the event that Gatherer refuses to gather the Subject Gas for a period of sixty (60) consecutive days causing Producer’s well(s) to be shut-in, Producer shall have the option, exercised solely at its discretion, to terminate the Agreement in its entirety insofar and only insofar as it pertains to Subject Gas produced from the affected well(s) by providing to Gatherer advance written notice thirty (30) days in advance of such termination.

17.2    Nothing herein shall be construed to require Producer to drill any well or to continue to operate any well which a prudent operator would not in like circumstances drill or continue to operate. Notwithstanding the foregoing, (a) Producer intends to produce the maximum volumes possible and commits to bring all wells currently shut in for economic purposes online as soon as practicable, but in no event later than July 1, 2016 and (b) Producer agrees that it will not shut-in or choke back wells for economic purposes during the calendar years of 2016 through the end of 2018 unless the well reaches the end of its useful life or safety, technical or mechanical reasons necessitate shutting-in or choking back the well.

17.3    Gatherer shall not be obligated to expand the Gathering System in order to provide capacity hereunder.

18. Term

This terms of this Agreement shall be effective from the Effective Date and, subject to the other provisions hereof, shall continue in full force and effect until the tenth anniversary of the date Producer first delivers Subject Gas to the Receipt Point(s) pursuant to the terms of this Agreement and shall be automatically renewed for one (1) year periods thereafter unless on or before one hundred eighty (180) days prior to the expiration of the primary term or the expiration of a one (1) year renewal period a Party provides written notice of termination to the other Party (the “Term”). For the avoidance of doubt, this Agreement shall become effective subject to and simultaneously with the "Closing" as such term is defined under the Asset Purchase Agreement.

19.    Regulatory Bodies

This Agreement and the provisions hereof shall be subject to all valid applicable federal, state, and local laws, orders, rules, and regulations. Producer and Gatherer have entered into this Agreement with the understanding, and in reliance on the fact, that this Agreement and/or performance of this Agreement are not and will not be subject to the jurisdiction or regulation of the Federal Energy Regulatory Commission. If this Agreement and/or performance of this Agreement becomes subject to such jurisdiction and/or regulation, this Agreement shall automatically terminate unless Producer and Gatherer

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agree, in writing, within thirty (30) days of the effective date of the attachment of any such jurisdiction and/or regulation, that this Agreement shall continue after such effective date.

20.    Disputes

20.1    Should a dispute arise between the Parties out of or in connection with this Agreement, the Parties shall promptly seek to resolve any such dispute by negotiations among the senior executives of the Parties who have the authority to settle such dispute (“Senior Executives”) prior to the initiation of any lawsuit. The Senior Executives shall meet at a mutually acceptable time and place within fifteen (15) days after such dispute arises and thereafter as often as they reasonably deem necessary to exchange relevant information and to attempt to resolve the dispute. All negotiations and communications pursuant to this Section shall be treated as compromise and settlement negotiations for purposes of the federal and state Rules of Evidence. If the dispute has not been resolved within thirty (30) days after the initial meeting of the Senior Executives, or such longer period as may be mutually agreed upon, either Party may initiate a lawsuit.

20.2    IN ANY SUIT FILED BY A PARTY TO RESOLVE A DISPUTE ARISING UNDER THIS AGREEMENT OR RELATED TO THE SERVICES PROVIDED HEREUNDER, EACH PARTY HEREBY COVENANTS AND AGREES TO TAKE ALL STEPS NECESSARY TO WAIVE A TRIAL BY JURY.

21.    Notices and Payments

Except for the initial telephonic notice of force majeure permitted under Section 16, any notice, request, demand, statement, or bill provided for in this Agreement shall be in writing and delivered by hand, mail, or email. All such written communications shall be effective upon receipt by the other party at the address of the Parties as follows:

Producer

Statements:            BlueStone Natural Resources II, LLC

2100 South Utica

Tulsa, OK 74114

Attn: John Redmond

Email: jredmond@bluestone-nr.com

Payments:            BlueStone Natural Resources II, LLC

2100 South Utica

Tulsa, OK 74114

Attn: John Redmond

Email: jredmond@bluestone-nr.com

Contractual:            BlueStone Natural Resources II, LLC

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PORTIONS OF THIS EXHIBIT DENOTED WITH THREE ASTERISKS (***) HAVE BEEN OMITTED PURSUANT TO A REQUEST FOR CONFIDENTIAL TREATMENT

2100 South Utica

Tulsa, OK 74114

Attn: John Redmond

Email: jredmond@bluestone-nr.com

Gatherer

Statements:            Cowtown Pipeline Partners L.P.

1200 Summit Avenue, Suite 320

Fort Worth, Texas 76102

Attn: Revenue Accounting

Payments:            Cowtown Pipeline Partners L.P.

1200 Summit Avenue, Suite 320

Fort Worth, Texas 76102

Attn: Accounting

Contractual:            Cowtown Pipeline Partners L.P.

700 Louisiana, Suite 2550

Houston, Texas 77002

Attn: VP of Commercial

Email: Darrel.hagerman@crestwoodlp.com

Any of the Parties may designate a further or different address by giving written notice to the other Parties.

22.    Right to Process the Gas

Producer agrees that Gatherer shall have the right to process, or cause to be processed, blend, or cause to be blended, the Subject Gas delivered hereunder for the extraction of natural gas liquids and other valuable components, to the extent that Gatherer or its affiliates constructs, acquires or otherwise obtains access to facilities capable of processing such Subject Gas. Upon written notice to Producer that Gatherer is ready and willing to exercise this right, the Parties will negotiate in good faith the terms and fees for the processing of the Subject Gas at any such facility, which terms and fees (i) shall be consistent with those then prevailing in the area for similar processing or blending and (ii) shall be set forth in an amendment to this Agreement or in a supplemental agreement between the Parties.

23.    Assignment

This Agreement shall be binding upon and inure to the benefit of the heirs, executors, administrators, successors, and assigns of the respective Parties, but no transfer of or succession to the interest of any Party, either wholly or partially, shall affect or bind the other Parties until it shall have been furnished with the original instrument or with the proper

30

PORTIONS OF THIS EXHIBIT DENOTED WITH THREE ASTERISKS (***) HAVE BEEN OMITTED PURSUANT TO A REQUEST FOR CONFIDENTIAL TREATMENT

proof that the claimant is legally entitled to such interest; provided, however, that in the case of any assignment by Producer (i) such assignment shall be further subject to the satisfaction by Producer’s assignee of the creditworthiness requirements of Section 12.6, and (ii) Producer’s assignee shall be required to expressly agree under such assignment to assume and be bound by all of the obligations of Producer under this Agreement.

24.    Miscellaneous

24.1    No waiver by any Party of any one or more defaults in the performance of any provision of this Agreement shall operate or be construed as a waiver of any other default or future defaults, whether of a like or different character.

24.2    No modification or amendment of the terms and provisions of this Agreement shall be made except by the execution of a written agreement by the Parties. This Agreement contains the entire agreement between the Parties and there are no oral promises, agreements, or warranties affecting it.

24.3    The headings in this Agreement are formulated and used for convenience only and shall not be deemed to affect the meaning or construction of any provisions of this Agreement.

24.4    This Agreement supersedes and replaces any other contract(s) or agreements(s) which may exist between the Parties covering the gathering or processing of the Subject Gas owned by Producer dedicated hereunder.

24.5    Nothing in this Agreement is intended to create a partnership or joint venture under state law or to render the Parties jointly and severally liable to any third party. Each of the Parties elects to be excluded from the provisions of Subchapter K, Chapter 1 of Subtitle A, of the Internal Revenue Code of 1986 pursuant to the provisions of Article 761(a) of such code and from any similar provisions of state law. Gatherer shall timely file such evidence of this election as may be required under applicable law.

24.6    Should any section, subsection, paragraph, subparagraph, or other portion of this Agreement be found invalid as a matter of law in a duly authorized court, or by a duly authorized government agency, then only that portion of this Agreement shall be invalid. The remainder of this Agreement which shall not have been found invalid shall remain in full force and effect.

24.7    THIS AGREEMENT, AND ALL QUESTIONS RELATING TO ITS VALIDITY, INTERPRETATION, PERFORMANCE, AND ENFORCEMENT (INCLUDING, WITHOUT LIMITATION, PROVISIONS CONCERNING LIMITATIONS OF ACTIONS) SHALL BE GOVERNED BY AND CONSTRUED IN ACCORDANCE WITH THE LAWS OF THE STATE OF TEXAS, NOTWITHSTANDING ANY CONFLICT-OF-LAWS DOCTRINES OF SUCH STATE

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PORTIONS OF THIS EXHIBIT DENOTED WITH THREE ASTERISKS (***) HAVE BEEN OMITTED PURSUANT TO A REQUEST FOR CONFIDENTIAL TREATMENT

OR OTHER JURISDICTION TO THE CONTRARY. ALL MATTERS LITIGATED BY OR BETWEEN THE PARTIES THAT INVOLVE THIS AGREEMENT, THE RELATIONSHIP OF THE PARTIES, OR ANY RELATED DOCUMENTS OR MATTERS HEREUNDER SHALL BE BROUGHT ONLY IN HOUSTON, HARRIS COUNTY, TEXAS.

24.8    This Agreement was prepared jointly by the Parties and not by any Party to the exclusion of the other. In the event an ambiguity or question of intent or interpretation arises, no presumption or burden of proof will arise favoring or disfavoring any Party by virtue of the authorship, or any greater involvement in the drafting, of any of the provisions of this Agreement.

24.9    The Parties warrant and represent that no promise, agreement, representation, inducement, or condition which is not herein expressed has been made to either Party by the other, or any agent or representative of either Party to the other, in executing this Agreement.  The Parties further warrant and represent they are not relying upon, and expressly disclaim, any such promise, agreement, representation, inducement, or condition which is not herein expressed in executing this Agreement. The Parties represents and warrant they are relying solely upon their own judgment in entering this Agreement.

24.10    This Agreement is being executed contemporaneously with the Parties’ Letter Agreement. The Parties represent, warrant, and agree this Agreement and the Letter Agreement collectively comprise one transaction.

[Signature Page Follows]

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PORTIONS OF THIS EXHIBIT DENOTED WITH THREE ASTERISKS (***) HAVE BEEN OMITTED PURSUANT TO A REQUEST FOR CONFIDENTIAL TREATMENT

IN WITNESS WHEREOF, the Parties have executed this Agreement in several originals as of the date and year written above.

PRODUCER

BlueStone Natural Resources II, LLC, a                                 Delaware limited liability company

By:    /s/ John Redwood            

Name:    John Redwood

Title:    President/Chief Executive Officer                    

GATHERER

Cowtown Pipeline Partners L.P., a Texas                             limited partnership

By:    Crestwood Gas Services Operating GP                                 LLC, its General partner

By:    J. Heath Deneke        

Name:    J. Heath Deneke

Title:    Chief Operating Officer and                                 President, Pipeline Services Group

33

PORTIONS OF THIS EXHIBIT DENOTED WITH THREE ASTERISKS (***) HAVE BEEN OMITTED PURSUANT TO A REQUEST FOR CONFIDENTIAL TREATMENT

EXHIBIT A

to the

GAS GATHERING AGREEMENT

[ALLIANCE AREA]

CONTRACT AREA; DEDICATED LEASES; DEDICATED WELLS

This Exhibit A is attached to the Gas Gathering Agreement (the “Agreement”) dated as of April 1, 2016, by and between BlueStone Natural Resources II, LLC, as Producer, and Cowtown Pipeline Partners L.P., as Gatherer, and made a part thereof for all purposes. All defined terms used herein shall have the same meaning as set forth in the Agreement.

Contract Area

Denton County, Texas

Tarrant County, Texas

With regard to Tarrant County, Gas that satisfies the quality specifications in Section 7.1(g) of the Cowtown Gas Gathering and Processing Agreement dated as of even date herewith shall be dedicated to such agreement and all other Gas produced or producible from wells in Tarrant County shall be dedicated to this Agreement.

Leases

See attached sheets.

Exhibit A, Page 1

3230471v2

PORTIONS OF THIS EXHIBIT DENOTED WITH THREE ASTERISKS (***) HAVE BEEN OMITTED PURSUANT TO A REQUEST FOR CONFIDENTIAL TREATMENT

ST	County	File ID	Lessor	Lease Dated	Recorded County	Vol/Book	Page	Instrument No.
TX	TARRANT AND DENTON	TX1210031.38	SUE A WORKS	5/16/2014	DENTON			2014-61290
TX	TARRANT AND DENTON	TX1210031.38	SUE A WORKS	5/16/2014	TARRANT			D214132772
TX	TARRANT AND DENTON	TX1210005.00	NORTEX MINERALS LP	5/1/2003	DENTON			2004-124550
TX	TARRANT AND DENTON	TX1210005.00	NORTEX MINERALS LP		TARRANT			D203315430
TX	TARRANT AND DENTON	TX1210005.00	NORTEX MINERALS LP	5/1/2003
TX	TARRANT AND DENTON	TX1210005.00	NORTEX MINERALS LP
TX	TARRANT AND DENTON	TX1210005.00	NORTEX MINERALS LP
TX	TARRANT AND DENTON	TX1210005.00	NORTEX MINERALS LP	5/1/2003
TX	TARRANT AND DENTON	TX1210005.00	NORTEX MINERALS LP
TX	TARRANT AND DENTON	TX1210011.01	WAUNITA L CLARK	8/12/2001	DENTON	4931	1803	101800
TX	TARRANT AND DENTON	TX1210011.01	WAUNITA L CLARK	8/12/2001	TARRANT			D203174562
TX	TARRANT AND DENTON	TX1210011.01	WAUNITA L CLARK	8/12/2001
TX	TARRANT AND DENTON	TX1210011.01	WAUNITA L CLARK	8/12/2001
TX	TARRANT AND DENTON	TX1210011.01	WAUNITA L CLARK	8/12/2001
	TARRANT AND DENTON	TX1210011.01	WAUNITA L CLARK	8/12/2001
TX	TARRANT AND DENTON	TX1210011.02	LAURA BETH BRINKER	8/12/2001	DENTON	4931	1807	101801
TX	TARRANT AND DENTON	TX1210011.02	LAURA BETH BRINKER	8/12/2001	TARRANT			D203174564
TX	TARRANT AND DENTON	TX1210011.02	LAURA BETH BRINKER	8/12/2001
TX	TARRANT AND DENTON	TX1210011.02	LAURA BETH BRINKER	8/12/2001
TX	TARRANT AND DENTON	TX1210011.02	LAURA BETH BRINKER	8/12/2001

TX	TARRANT AND DENTON	TX1210011.02	LAURA BETH BRINKER	8/12/2001
TX	TARRANT AND DENTON	TX1210011.03	JACK CROWLEY ET AL	8/27/2001	DENTON	4931	1812	101802
TX	TARRANT AND DENTON	TX1210011.03	JACK CROWLEY ET AL	8/27/2001	TARRANT			D203174561
TX	TARRANT AND DENTON	TX1210011.03	JACK CROWLEY ET AL	8/27/2001
TX	TARRANT AND DENTON	TX1210011.03	JACK CROWLEY ET AL	8/27/2001
TX	TARRANT AND DENTON	TX1210011.03	JACK CROWLEY ET AL	8/27/2001
TX	TARRANT AND DENTON	TX1210011.03	JACK CROWLEY ET AL	8/27/2001
TX	TARRANT AND DENTON	TX1210011.03	JACK CROWLEY ET AL	8/27/2001
TX	TARRANT AND DENTON	TX1210011.03	JACK CROWLEY ET AL	8/27/2001
TX	TARRANT AND DENTON	TX1210012.01	DR WELLS O STEPHENS EST	12/17/2001	DENTON	5000	1164	4043
TX	TARRANT AND DENTON	TX1210012.01	DR WELLS O STEPHENS EST	12/17/2001	TARRANT			D202037586
TX	TARRANT AND DENTON	TX1210012.02	DR C B KENDALL EST	12/17/2001	DENTON	5000	1169	4044
TX	TARRANT AND DENTON	TX1210012.02	DR C B KENDALL EST	12/17/2001	TARRANT			D202037587
TX	TARRANT AND DENTON	TX1210026.01	PBBM NORTHLAKE LTD	3/2/2009	DENTON			2009-60422
TX	TARRANT AND DENTON	TX1210026.01	PBBM NORTHLAKE LTD	3/2/2009
TX	TARRANT AND DENTON	TX1210026.01	PBBM NORTHLAKE LTD	3/2/2009
TX	TARRANT AND DENTON	TX1210026.01	PBBM NORTHLAKE LTD	3/2/2009
TX	TARRANT AND DENTON	TX1210031.13	LUMINANT MINERAL DEVELOPMENT	3/2/2010	DENTON			2010-22559
TX	TARRANT AND DENTON	TX1210031.13	LUMINANT MINERAL DEVELOPMENT	3/2/2010	TARRANT			D210047137
TX	TARRANT AND DENTON	TX1210031.14	JOHN PORTER FARMS INC	4/21/2014	DENTON			2014-41356
TX	TARRANT AND DENTON	TX1210031.14	JOHN PORTER FARMS INC	4/21/2014	TARRANT			D214084785

Exhibit A, Page 2

3230471v2

PORTIONS OF THIS EXHIBIT DENOTED WITH THREE ASTERISKS (***) HAVE BEEN OMITTED PURSUANT TO A REQUEST FOR CONFIDENTIAL TREATMENT

TX	TARRANT AND DENTON	TX1210031.15	BOB CATES ET UX	4/23/2014	DENTON	2014-41354
TX	TARRANT AND DENTON	TX1210031.15	BOB CATES ET UX	4/23/2014	TARRANT	D214084785
TX	TARRANT AND DENTON	TX1210031.16	JOE CATES ET UX	4/23/2014	DENTON	2014-41355
TX	TARRANT AND DENTON	TX1210031.20	PAUL D COPENHAVER JR ET UX	5/12/2014	DENTON	2014-49254
TX	TARRANT AND DENTON	TX1210031.27	JOHN MURLEY	7/24/2014	DENTON	2014-82676
TX	TARRANT AND DENTON	TX1210031.27	JOHN MURLEY	7/24/2014	TARRANT	D215142691
TX	TARRANT AND DENTON	TX1210031.28	SUE WORKS	5/16/2014	DENTON	2014-61290
TX	TARRANT AND DENTON	TX1210031.28	SUE WORKS	5/16/2014	TARRANT	D214132772
TX	TARRANT AND DENTON	TX1210031.30	PAUL A PINSON ET UX	8/13/2014	TARRANT	D214195144
TX	TARRANT AND DENTON	TX1210031.31	DEBORAH L FLORES	8/13/2014	TARRANT	D214195145
TX	TARRANT AND DENTON	TX1210031.32	WILLIAM A KIRK	8/18/2014	DENTON	2014-100907
TX	TARRANT AND DENTON	TX1210031.32	WILLIAM A KIRK	8/18/2014	TARRANT	D214195142
TX	TARRANT AND DENTON	TX1210031.36	RICHARD N BROWN ET UX	6/26/2014	DENTON	2014-109197
TX	TARRANT AND DENTON	TX1210031.36	RICHARD N BROWN ET UX	6/26/2014	TARRANT	D214225480
TX	TARRANT AND DENTON	TX1210031.37	PAUL DON CRUSE ET UX	10/8/2014	DENTON	2014-109196
TX	TARRANT AND DENTON	TX1210031.37	PAUL DON CRUSE ET UX		TARRANT	D214225481
TX	TARRANT AND DENTON	TX1210031.39	KENNETH MILLER	10/16/2014	DENTON	2014-122345
TX	TARRANT AND DENTON	TX1210031.39	KENNETH MILLER	10/16/2014	TARRANT	D214256085
TX	TARRANT AND DENTON	TX1210031.41	LARRY CARSON TIDWELL ET UX	11/6/2014	DENTON	2015-1219
TX	TARRANT AND DENTON	TX1210031.41	LARRY CARSON TIDWELL ET UX	11/6/2014	TARRANT	D214275922
TX	TARRANT AND DENTON	TX1210031.46	RAYA NEVEEN REDDY ET UX	12/10/2014	DENTON	2015-1217

Exhibit A, Page 3

3230471v2

PORTIONS OF THIS EXHIBIT DENOTED WITH THREE ASTERISKS (***) HAVE BEEN OMITTED PURSUANT TO A REQUEST FOR CONFIDENTIAL TREATMENT

TX	TARRANT AND DENTON	TX1210031.46	RAYA NEVEEN REDDY ET UX	12/10/2014	TARRANT	D214275920
TX	TARRANT AND DENTON	TX1210031.53	SHERRY BUGG	10/24/2014	DENTON	2015-8217
TX	TARRANT AND DENTON	TX1210031.53	SHERRY BUGG	10/24/2014	TARRANT	D215013067
TX	TARRANT AND DENTON	TX1210031.56	JAMES R HAIRE ET UX	12/18/2014	DENTON	2015-14690
TX	TARRANT AND DENTON	TX1210031.56	JAMES R HAIRE ET UX		TARRANT	D215026331
TX	TARRANT AND DENTON	TX1210031.57	DALE GLEN & STELLA MARIE EDELMAN	1/21/2015	DENTON	2015-14688
TX	TARRANT AND DENTON	TX1210031.57	DALE GLEN & STELLA MARIE EDELMAN	1/21/2015	TARRANT	D215046447
TX	TARRANT AND DENTON	TX1210031.59	KEVIN SIMMONS	2/5/2015	DENTON	2015-26717
	TARRANT AND DENTON	TX1210031.59	KEVIN SIMMONS		TARRANT	D215046448
TX	TARRANT AND DENTON	TX1210031.60	ANGELA DAONNE RAWIE	8/19/2014	DENTON	2015-26718
	TARRANT AND DENTON	TX1210031.60	ANGELA DAONNE RAWIE		TARRANT	D215052665
TX	TARRANT	TX1210031.54	SUSAN BURKE	1/8/2015	TARRANT	D215021177
TX	TARRANT	TX1210031.65	RICK M WATSON ET UX	1/5/2015	TARRANT	D215118278
TX	TARRANT	TX4390439.00	PERRY N BRANUM ET UX	7/4/2005	TARRANT	D205385729
TX	TARRANT	TX4390439.00	PERRY N BRANUM ET UX	7/4/2005
TX	TARRANT	TX4390440.00	RICKY L SONNEVELT	7/5/2005	TARRANT	D205385532
TX	TARRANT	TX4390441.00	SANDRA G SMITH	7/4/2005	TARRANT	D205385531
TX	TARRANT	TX4390442.00	JOYCE L PLUMMER	7/4/2005	TARRANT	D205385527
TX	TARRANT	TX4390443.00	MARJORIE FAY WATT	7/4/2005	TARRANT	D205385541
TX	TARRANT	TX4390444.00	BENNEY MARTIN	7/4/2005	TARRANT	D205385542
TX	TARRANT	TX4390446.00	ROBERT L JOHNSON	3/27/2006	TARRANT	D206194134
TX	TARRANT	TX4390447.00	ANTONIO GARCIA ET UX	3/27/2006	TARRANT	D206194133
TX	TARRANT	TX4390448.00	GLADYS S HAYS TRUSTEE ETAL	3/27/2006	TARRANT	D206194131
TX	TARRANT	TX4390449.00	SUNTRUST EQUITY FUNDING LL	1/17/2006	TARRANT	D206085659
TX	TARRANT	TX4390450.00	TANYA L LAIRD	8/29/2005	TARRANT	D205385539
TX	TARRANT	TX4390451.00	GLADYS HAYS	7/5/2005	TARRANT	D205385736
TX	TARRANT	TX4390452.00	JIMMY EARL MCMILLIN	7/14/2005	TARRANT	D205385544
TX	TARRANT	TX4390452.00	JIMMY EARL MCMILLIN	7/14/2005

Exhibit A, Page 4

3230471v2

PORTIONS OF THIS EXHIBIT DENOTED WITH THREE ASTERISKS (***) HAVE BEEN OMITTED PURSUANT TO A REQUEST FOR CONFIDENTIAL TREATMENT

TX	TARRANT	TX4390453.00	SUSAN E EASTHAM ET VIR	7/4/2005	TARRANT	D205385732
TX	TARRANT	TX4390455.00	PAUL POLIZZO ET AL	7/4/2005	TARRANT	D205385528
TX	TARRANT	TX4390456.00	REX V BAGBY	3/27/2006	TARRANT	D206194128
TX	TARRANT	TX4390456.00	REX V BAGBY	3/27/2006
TX	TARRANT	TX4390457.00	BONNIE M PALMER	7/4/2005	TARRANT	D205385525
TX	TARRANT	TX4390458.00	STEVEN A FUSCO	7/4/2005	TARRANT	D205358012
TX	TARRANT	TX4390459.00	FIRST BAPTIST CHURCH HASLE	8/18/2005	TARRANT	D205385734
TX	TARRANT	TX4390460.00	WILLIAM E FRISBIE	7/4/2005	TARRANT	D205385735
TX	TARRANT	TX4390460.00	WILLIAM E FRISBIE	7/4/2005
TX	TARRANT	TX4390461.00	CHARLES T JACKSON	7/4/2005	TARRANT	D205385535
TX	TARRANT	TX4390462.00	ALICE M LAIRD ESTATE	7/4/2005	TARRANT	D205385537
TX	TARRANT	TX4390463.00	CINDY J LAIRD	8/11/2005	TARRANT	D205385538
TX	TARRANT	TX4390464.00	MAUDIE C PIKE	7/4/2005	TARRANT	D205385526
TX	TARRANT	TX4390466.00	EULALIA G WALSH	7/4/2005	TARRANT	D205385521
TX	TARRANT	TX4390469.00	MARY ANN CLAUNCH	7/4/2005	TARRANT	D205385730
TX	TARRANT	TX4390469.00	MARY ANN CLAUNCH	7/4/2005
TX	TARRANT	TX4390471.00	NORTEX MINERALS LP	1/1/2006	TARRANT	D206083608
TX	TARRANT	TX4390471.00	NORTEX MINERALS LP	1/1/2006
TX	TARRANT	TX4390471.00	NORTEX MINERALS LP	1/1/2006
TX	TARRANT	TX4390472.00	NORTEX MINERALS LP	3/1/2006	TARRANT	D206157277
TX	TARRANT	TX4390472.00	NORTEX MINERALS LP	3/1/2006
TX	TARRANT	TX4390472.00	NORTEX MINERALS LP	3/1/2006
TX	TARRANT	TX4390472.00	NORTEX MINERALS LP	3/1/2006
TX	TARRANT	TX4390473.00	LUTHER J LEE	3/27/2006	TARRANT	D206194129
TX	TARRANT	TX4390474.00	NORTEX MINERALS LP	7/1/2006	TARRANT	D206264635
TX	TARRANT	TX4390474.00	NORTEX MINERALS LP	7/1/2006
TX	TARRANT	TX4390474.00	NORTEX MINERALS LP	7/1/2006
TX	TARRANT	TX4390475.00	JOEL BULLARD ET AL	7/4/2005	TARRANT	D205296490
TX	TARRANT	TX4390476.00	MARVIN C HICKS ET UX	7/4/2005	TARRANT	D205275273
TX	TARRANT	TX4390478.00	JOLENE J OWEN	7/4/2005	TARRANT	D205296491
TX	TARRANT	TX4390479.00	SABRINA CUSTOM HOMES INC	7/4/2005	TARRANT	D205278478
TX	TARRANT	TX4390480.00	STEPHEN V SALADINO ET UX	7/4/2005	TARRANT	D205278476
TX	TARRANT AND DENTON	TX4390481.00	NORTEX MINERALS LP	9/1/2005	DENTON	2008-51627
TX	TARRANT AND DENTON	TX4390481.00	NORTEX MINERALS LP	9/1/2005	TARRANT	D206181584

Exhibit A, Page 5

3230471v2

PORTIONS OF THIS EXHIBIT DENOTED WITH THREE ASTERISKS (***) HAVE BEEN OMITTED PURSUANT TO A REQUEST FOR CONFIDENTIAL TREATMENT

TX	TARRANT AND DENTON	TX4390481.00	NORTEX MINERALS LP	9/1/2005
TX	TARRANT AND DENTON	TX4390481.00	NORTEX MINERALS LP	9/1/2005
TX	TARRANT AND DENTON	TX4390481.00	NORTEX MINERALS LP	9/1/2005
TX	TARRANT AND DENTON	TX4390481.00	NORTEX MINERALS LP	9/1/2005
TX	TARRANT	TX4390482.00	JERRY REYNOLDS ET UX	9/27/2004	TARRANT	D204342258
TX	TARRANT	TX4390483.00	FRANCES BALTZELLE ET AL	12/14/2004	TARRANT	D205006114
TX	TARRANT	TX4390484.00	CITY OF FORT WORTH	7/5/2005	TARRANT	D205228842
TX	TARRANT	TX4390488.00	NORTEX MINERALS LP	8/25/2004	TARRANT	D204331034
TX	TARRANT	TX4390488.00	NORTEX MINERALS LP	8/25/2004
TX	TARRANT	TX4390488.00	NORTEX MINERALS LP	8/25/2004	LEASE IS ONLY TARRANT COUNTY
TX	TARRANT	TX4390490.00	DUNCAN TRUST, GEORGIA REEV	7/19/2004	TARRANT	D204251927
TX	TARRANT	TX4390492.00	NORTEX MINERALS LP	8/1/2005	TARRANT	D206079752
TX	TARRANT	TX4390492.00	NORTEX MINERALS LP	8/1/2005
TX	TARRANT	TX4390492.00	NORTEX MINERALS LP	8/1/2005	LEASE IS ONLY TARRANT COUNTY
TX	TARRANT	TX4390493.00	DEWEY EUGENE COZART ET AL	1/31/2003	TARRANT	D203086385
TX	TARRANT	TX4390493.00	DEWEY EUGENE COZART ET AL	1/31/2003
TX	TARRANT	TX4390494.01	RANDALL L KUYKENDALL	4/13/2007	TARRANT	D207160623
TX	TARRANT	TX4390496.00	JOAN MCKINLEY	5/21/2007	TARRANT	D207298724
TX	TARRANT	TX4390497.00	MATTHIAS T SNOW ET UX	5/1/2007	TARRANT	D207239253
TX	TARRANT	TX4390498.00	CITY OF HASLET TEXAS	7/28/2006	TARRANT	D207117708
TX	TARRANT AND DENTON	TX4390499.01	ANNE CARTWRIGHT FAMILY TR	3/18/2003	DENTON	2008-65818
TX	TARRANT AND DENTON	TX4390499.01	ANNE CARTWRIGHT FAMILY TR		TARRANT	D203127485
TX	TARRANT AND DENTON	TX4390499.02	VICTORIA NEWTON TR	3/15/2003	DENTON	2008-65819
TX	TARRANT AND DENTON	TX4390499.02	VICTORIA NEWTON TR	3/15/2003	TARRANT	D203325911
TX	TARRANT AND DENTON	TX4390499.03	ELIZABETH P CARVER ESTATE	3/15/2003	DENTON	2008-65820
TX	TARRANT AND DENTON	TX4390499.03	ELIZABETH P CARVER ESTATE	3/15/2003	TARRANT	D203325910
TX	TARRANT AND DENTON	TX4390499.04	JEROME CARTWRIGHT IND	3/18/2003	DENTON	2008-65821

Exhibit A, Page 6

3230471v2

PORTIONS OF THIS EXHIBIT DENOTED WITH THREE ASTERISKS (***) HAVE BEEN OMITTED PURSUANT TO A REQUEST FOR CONFIDENTIAL TREATMENT

TX	TARRANT AND DENTON	TX4390499.04	JEROME CARTWRIGHT IND	3/18/2003	TARRANT	D203127484
TX	TARRANT AND DENTON	TX4390499.05	JEAN CARTWRIGHT DICKSON	3/18/2003	DENTON	2008-65822
TX	TARRANT AND DENTON	TX4390499.05	JEAN CARTWRIGHT DICKSON	3/18/2003	TARRANT	D203127483
TX	TARRANT AND DENTON	TX4390500.00	NORTEX MINERALS LP	5/1/2008	TARRANT	D208187570
TX	TARRANT AND DENTON	TX4390500.00	NORTEX MINERALS LP	5/1/2008
TX	TARRANT AND DENTON	TX4390500.00	NORTEX MINERALS LP	5/1/2008
TX	TARRANT AND DENTON	TX4390501.00	NORTEX MINERALS LP	1/15/2007	TARRANT	D207117705
TX	TARRANT AND DENTON	TX4390501.00	NORTEX MINERALS LP	1/15/2007
TX	TARRANT AND DENTON	TX4390501.00	NORTEX MINERALS LP	1/15/2007
TX	TARRANT AND DENTON	TX4390501.00	NORTEX MINERALS LP	1/15/2007
TX	TARRANT	TX4390502.00	BELL HELICOPTER TEXTRON IN	7/14/2006	TARRANT	D206297170
TX	TARRANT	TX4390503.00	JOHN D WASHBURN	7/4/2005	TARRANT	D205385522
TX	TARRANT	TX4390504.00	FERNANDO MORENO SR	7/4/2005	TARRANT	D205385545
TX	TARRANT	TX4390507.01	RICHARD WHATLEY	1/28/2007	TARRANT	D207145911
TX	TARRANT	TX4390507.02	R W WHATLEY JR	1/28/2007	TARRANT	D207107620
TX	TARRANT	TX4390507.03	CHARLES J WHATLEY	1/28/2007	TARRANT	D207107652
TX	TARRANT	TX4390507.04	LINDA C KILLIAN	1/28/2007	TARRANT	D207107615
TX	TARRANT	TX4390507.05	BABIE RUTH PRICE HILL	1/28/2007	TARRANT	D207107619
TX	TARRANT	TX4390507.06	DOROTHY WHATLEY DANIEL	1/28/2007	TARRANT	D207107618
TX	TARRANT	TX4390507.07	LYNDA WHATLEY FRAZIER	1/28/2007	TARRANT	D207107617
TX	TARRANT	TX4390507.08	JANETT ANN WHATLEY ROSE	1/28/2007	TARRANT	D207107616
TX	TARRANT	TX4390507.09	STEPHEN L PRICE JR	1/28/2007	TARRANT	D207107621
TX	TARRANT	TX4390507.10	SUSAN LORAINE DE MELIK	1/28/2007	TARRANT	D207128283
TX	TARRANT	TX4390507.11	FRANCES WHATLEY SHELL	1/28/2007	TARRANT	D207107651
TX	TARRANT	TX4390507.12	THOMAS EDMUND WHATLEY	1/28/2007	TARRANT	D207107646
TX	TARRANT	TX4390507.13	WANDA WHATLEY PERRY	1/28/2007	TARRANT	D207107647
TX	TARRANT	TX4390507.14	EDWARD T SUTTON	1/28/2007	TARRANT	D207107648
TX	TARRANT	TX4390507.15	WYLENNE WHATLEY MCCULLERS	1/28/2007	TARRANT	D207107650

Exhibit A, Page 7

3230471v2

PORTIONS OF THIS EXHIBIT DENOTED WITH THREE ASTERISKS (***) HAVE BEEN OMITTED PURSUANT TO A REQUEST FOR CONFIDENTIAL TREATMENT

TX	TARRANT	TX4390507.16	BOBBY ODELL WHATLEY	1/28/2007	TARRANT	D207107649
TX	TARRANT	TX4390507.17	CLIFTON A WHATLEY JR	1/28/2007	TARRANT	D207145910
TX	TARRANT	TX4390507.18	JUANITA POWELL	3/27/2006	TARRANT	D206194132
TX	TARRANT	TX4390509.01	GREG A LYON	9/10/2007	TARRANT	D207376727
TX	TARRANT	TX4390509.02	BRADLEY G FELDKAMP	9/10/2007	TARRANT	D207376726
TX	TARRANT	TX4390510.01	JOYCE L PLUMMER	3/27/2006	TARRANT	D206194130
TX	TARRANT	TX4390510.02	LOUIS G ULLRICH	3/21/2007	TARRANT	D207160622
TX	TARRANT	TX4390510.03	CHARLES ULLRICH	3/21/2007	TARRANT	D208088240
TX	TARRANT	TX4390510.04	ETHAL LEAN MCWAIN	1/28/2008	TARRANT	D208085146
TX	TARRANT	TX4390511.99	NORTEX MINERALS LP	8/8/2008	TARRANT	D208313583
TX	TARRANT	TX4390564.00	THOMAS K SENNE ET UX	11/15/2007	TARRANT	D208086932
TX	TARRANT	TX4390565.00	CHARLES C COONS ET UX	4/3/2008	TARRANT	D208167620
TX	TARRANT	TX4390566.00	FARRUKH AZIM	4/3/2008	TARRANT	D208157508
TX	TARRANT	TX4390567.00	MARK E DUNN ET UX	11/15/2007	TARRANT	D208086950
TX	TARRANT	TX4390568.00	BYRON S JOBE	11/15/2007	TARRANT	D208086969
TX	TARRANT	TX4390569.00	BRANDON L MILLER ET UX	4/3/2008	TARRANT	D208157530
TX	TARRANT	TX4390570.00	TEDDIE W ROCKWELL ET UX	4/3/2008	TARRANT	D208167621
TX	TARRANT	TX4390571.00	J DREW MICHAEL	4/3/2008	TARRANT	D208157465
TX	TARRANT	TX4390572.00	WILLIAM STEWART ET UX	11/15/2007	TARRANT	D208086900
TX	TARRANT	TX4390573.00	DAVID HANNAH ET UX	11/15/2007	TARRANT	D208086905
TX	TARRANT	TX4390574.00	LINDSAY M HARMON AIF YATES	4/3/2008	TARRANT	D208167624
TX	TARRANT	TX4390575.00	STACEY WHITEHEAD	11/15/2007	TARRANT	D208086959
TX	TARRANT	TX4390576.00	LORETTA A HOLCOMBE	4/3/2008	TARRANT	D208157469
TX	TARRANT	TX4390577.00	SUZANNAH P NIELSEN ET VIR	4/3/2008	TARRANT	D208157478
TX	TARRANT	TX4390578.00	LEROY D SWAMMY ET UX	11/15/2007	TARRANT	D208086948
TX	TARRANT	TX4390579.00	DARREN J COLLINS ET UX	2/7/2008	TARRANT	D208086963
TX	TARRANT	TX4390580.00	DONALD J PITTENGER JR	2/7/2008	TARRANT	D208086955
TX	TARRANT	TX4390581.00	JACQUELINE K RITZ MELMAN	11/15/2007	TARRANT	D208086907
TX	TARRANT	TX4390582.00	RHONDA K WHITINGTON	11/15/2007	TARRANT	D208086917
TX	TARRANT	TX4390583.00	SHANE GULDBRANSEN ET UX	2/7/2008	TARRANT	D208086979
TX	TARRANT	TX4390584.00	LAURA BRICE	4/3/2008	TARRANT	D208157529
TX	TARRANT	TX4390585.00	ALFREDO MADRID	11/15/2007	TARRANT	D208086975
TX	TARRANT	TX4390586.00	CHRISTOPHER D CRAWFORD	4/3/2008	TARRANT	D208157509
TX	TARRANT	TX4390587.00	SPENCER A MCFARLAND ET UX	11/15/2007	TARRANT	D208086890
TX	TARRANT	TX4390588.00	MARCO TORO ET AL	11/15/2007	TARRANT	D208086886

Exhibit A, Page 8

3230471v2

PORTIONS OF THIS EXHIBIT DENOTED WITH THREE ASTERISKS (***) HAVE BEEN OMITTED PURSUANT TO A REQUEST FOR CONFIDENTIAL TREATMENT

TX	TARRANT	TX4390597.00	CITY OF FORT WORTH	8/1/2008	TARRANT	D208410221
TX	TARRANT	TX4390599.00	JAMIE CARMACK ET UX	11/15/2007	TARRANT	D208086913
TX	TARRANT	TX4390600.00	DAVID ALLEN BACH ET UX	3/30/2008	TARRANT	D208157534
TX	TARRANT	TX4390601.00	SHERRY L GRAY KENNEL KARE	3/15/2008	TARRANT	D208157459
TX	TARRANT	TX4390602.00	CHARLENE STEWART JACKSON I	4/21/2008	TARRANT	D208157533
TX	TARRANT	TX4390603.00	JAMES K GRAHAM ET UX	2/7/2008	TARRANT	D208086974
TX	TARRANT	TX4390604.00	JOHN M HUGGARD ET UX	11/15/2007	TARRANT	D208086973
TX	TARRANT	TX4390605.00	BRIAN L SEEFELDT ET UX	11/15/2007	TARRANT	D208086922
TX	TARRANT	TX4390606.00	BRYAN PHILLIPS ET UX	11/15/2007	TARRANT	D208086952
TX	TARRANT	TX4390607.00	DEREK W PORTER ET UX	11/15/2007	TARRANT	D208086931
TX	TARRANT	TX4390608.00	MARK T BASHAM ET UX	11/15/2007	TARRANT	D208086972
TX	TARRANT	TX4390609.00	AUGUSTIN MANTEZOLO ET UX	11/15/2007	TARRANT	D208086996
TX	TARRANT	TX4390610.00	VICTOR CHACON	11/15/2007	TARRANT	D208086895
TX	TARRANT	TX4390611.00	HOLLY A TEWKSBURY ET VIR	11/15/2007	TARRANT	D208086986
TX	TARRANT	TX4390612.00	DANIEL E RICHARDSON	11/15/2007	TARRANT	D208157457
TX	TARRANT	TX4390613.00	LOST SPURS RANCH APARTMENT	3/15/2008	TARRANT	D208157535
TX	TARRANT	TX4390614.00	ARTHUR LYON JR	11/15/2007	TARRANT	D208086887
TX	TARRANT	TX4390615.00	JOSE FRANCISCO OLGUIN	11/15/2007	TARRANT	D208086945
TX	TARRANT	TX4390616.00	KELLY A STANBERY	11/15/2007	TARRANT	D208086941
TX	TARRANT	TX4390617.00	JUSTIN BERNDT ET UX	4/3/2008	TARRANT	D208157482
TX	TARRANT	TX4390618.00	PAMELA TENNISON	4/3/2008	TARRANT	D208191990
TX	TARRANT	TX4390619.00	FRANK S DURHAM III ET UX	4/3/2008	TARRANT	D208157518
TX	TARRANT	TX4390620.00	CASSANDRA WATKINS	4/3/2008	TARRANT	D208241463
TX	TARRANT	TX4390621.00	JAMES R KARG ET UX	4/10/2008	TARRANT	D208157460
TX	TARRANT	TX4390622.00	CHARLES DAVID MARSH ET UX	4/10/2008	TARRANT	D208157461
TX	TARRANT	TX4390623.00	MARY ANN DAWSON	4/3/2008	TARRANT	D208157477
TX	TARRANT	TX4390625.00	MARK HICKOK & TROY HODGES	11/15/2007	TARRANT	D208086980
TX	TARRANT	TX4390626.00	CHANDLER CROUCH ET UX	4/3/2008	TARRANT	D208157532
TX	TARRANT	TX4390627.00	PABLO XIQUES/ KAREN XIQUES	4/3/2008	TARRANT	D208157499
TX	TARRANT	TX4390628.00	KEVIN MORRIS ET UX	4/3/2008	TARRANT	D208157464
TX	TARRANT	TX4390629.00	RICARDO SALAS ET UX	11/15/2007	TARRANT	D208086984
TX	TARRANT	TX4390630.00	IVAN CHARLES MCBRIDE ET UX	11/15/2007	TARRANT	D208086946
TX	TARRANT	TX4390631.00	STERLING L MULLIGAN ET UX	11/15/2007	TARRANT	D208086953
TX	TARRANT	TX4390632.00	DAVID R PETERSON ET UX	11/15/2007	TARRANT	D208086971
TX	TARRANT	TX4390633.00	ANDREW A BRINSON ET UX	2/7/2008	TARRANT	D208086954

Exhibit A, Page 9

3230471v2

PORTIONS OF THIS EXHIBIT DENOTED WITH THREE ASTERISKS (***) HAVE BEEN OMITTED PURSUANT TO A REQUEST FOR CONFIDENTIAL TREATMENT

TX	TARRANT	TX4390634.00	RODNEY GEISLER ET UX	11/15/2007	TARRANT	D208086909
TX	TARRANT	TX4390635.00	APUL LUMBANTOBING	11/15/2007	TARRANT	D208086911
TX	TARRANT	TX4390636.00	STEVEN B MOOTY ET UX	11/15/2007	TARRANT	D208157455
TX	TARRANT	TX4390637.00	KEVIN B TROTMAN ET U X	2/7/2008	TARRANT	D208086957
TX	TARRANT	TX4390638.00	LOUIS A REED ET UX	4/3/2008	TARRANT	D208157484
TX	TARRANT	TX4390639.00	NICK S BEAM ET UX	4/3/2008	TARRANT	D208157488
TX	TARRANT	TX4390640.00	JASON W CHRISTIAN ET UX	4/3/2008	TARRANT	D208157497
TX	TARRANT	TX4390641.00	STEPHEN E ANDERSON ET UX	4/3/2008	TARRANT	D208157491
TX	TARRANT	TX4390642.00	MARKUS L MURRAY ET UX	4/3/2008	TARRANT	D208157494
TX	TARRANT	TX4390643.00	HOWARD ROUTON ET UX	11/15/2007	TARRANT	D208086908
TX	TARRANT	TX4390644.00	DEREK BAKER ET UX	11/15/2007	TARRANT	D208086935
TX	TARRANT	TX4390646.00	TIMOTHY A COBB	11/15/2007	TARRANT	D208086940
TX	TARRANT	TX4390647.00	LARRY CERVANTES ET UX	4/3/2008	TARRANT	D208157507
TX	TARRANT	TX4390648.00	JAMES B IRWIN	2/7/2008	TARRANT	D208086960
TX	TARRANT	TX4390649.00	MARCOS NEVAREZ ET UX	2/7/2008	TARRANT	D208086958
TX	TARRANT	TX4390651.00	JON E RUTLEDGE ET UX	11/15/2007	TARRANT	D208086919
TX	TARRANT	TX4390652.00	JODY R HUCKABY	11/15/2007	TARRANT	D208086933
TX	TARRANT	TX4390653.00	MICHELE PIEROTTI	11/15/2007	TARRANT	D208086899
TX	TARRANT	TX4390654.00	PENNI L BURT	2/7/2008	TARRANT	D208086967
TX	TARRANT	TX4390655.00	SYLVIA RAMOS	11/15/2007	TARRANT	D208086927
TX	TARRANT	TX4390656.00	LILLIE ANN GLOVER ET AL	11/15/2007	TARRANT	D208086982
TX	TARRANT	TX4390658.00	SHANNON TODD FERGUSON	11/15/2007	TARRANT	D208086928
TX	TARRANT	TX4390659.00	RICHARD S BRIGGS ET UX	11/15/2007	TARRANT	D208086989
TX	TARRANT	TX4390660.00	LEVI J MILLER ET UX	11/15/2007	TARRANT	D208086926
TX	TARRANT	TX4390661.00	DEREK SCEARCE ET UX	11/15/2007	TARRANT	D208086898
TX	TARRANT	TX4390662.00	MARTIN RAMOS JR ET UX	11/15/2007	TARRANT	D208086925
TX	TARRANT	TX4390663.00	HOWELL FINNIGAN ET UX	11/15/2007	TARRANT	D208086951
TX	TARRANT	TX4390664.00	BRIAN ALLEN ET UX	11/15/2007	TARRANT	D208086936
TX	TARRANT	TX4390665.00	DAVID THIBODEAUX ET UX	11/15/2007	TARRANT	D208086904
TX	TARRANT	TX4390666.00	KELLI PHILLIPS	4/3/2008	TARRANT	D208157476
TX	TARRANT	TX4390667.00	NANCY E REID	4/3/2008	TARRANT	D208167622
TX	TARRANT	TX4390668.00	REX DILLINGHAM	4/3/2008	TARRANT	D208157467
TX	TARRANT	TX4390669.00	BRETT SCHRITTER ET UX	4/3/2008	TARRANT	D208157480
TX	TARRANT	TX4390670.00	ADAN RAMIREZ ET UX	4/3/2008	TARRANT	D208157474
TX	TARRANT	TX4390671.00	JUAN F REALEGENO ET UX	4/3/2008	TARRANT	D208157470

Exhibit A, Page 10

3230471v2

PORTIONS OF THIS EXHIBIT DENOTED WITH THREE ASTERISKS (***) HAVE BEEN OMITTED PURSUANT TO A REQUEST FOR CONFIDENTIAL TREATMENT

TX	TARRANT	TX4390672.00	JAMES M FEARS IV ET UX	4/3/2008	TARRANT	D208157479
TX	TARRANT	TX4390673.00	JOSE ANTONIO CINTRON ET UX	4/3/2008	TARRANT	D208157505
TX	TARRANT	TX4390674.00	IVAN WINROTH AIF DIEGO D	4/3/2008	TARRANT	D208167623
TX	TARRANT	TX4390675.00	JEREMY W FINCH ET UX	4/3/2008	TARRANT	D208157466
TX	TARRANT	TX4390676.00	DEBRA FITTS	11/15/2007	TARRANT	D208086889
TX	TARRANT	TX4390678.00	DOROTHY COSAND	4/3/2008	TARRANT	D208157492
TX	TARRANT	TX4390679.00	SABRA L DAGEL LAMAR	4/3/2008	TARRANT	D208157490
TX	TARRANT	TX4390680.00	MATTHEW S HOFFMAN	4/3/2008	TARRANT	D208157495
TX	TARRANT	TX4390681.00	FELIX MORALES ET UX	4/3/2008	TARRANT	D208157493
TX	TARRANT	TX4390682.00	JENNIFER DAVIS BYRD	4/3/2008	TARRANT	D208157496
TX	TARRANT	TX4390683.00	TIMOTHY S ASHWORTH	4/3/2008	TARRANT	D208157525
TX	TARRANT	TX4390684.00	CHRISTOPHER G STEVENS	4/3/2008	TARRANT	D208157517
TX	TARRANT	TX4390685.00	JOHN SCOTT JOHNSON ET UX	4/3/2008	TARRANT	D208157521
TX	TARRANT	TX4390686.00	DAVID A MARTIN ET UX	4/3/2008	TARRANT	D208157487
TX	TARRANT	TX4390687.00	PAUL A ROBINSON ET UX	4/3/2008	TARRANT	D208157527
TX	TARRANT	TX4390688.00	CHRISTOPHER W RAPPLEYE ET	4/3/2008	TARRANT	D208157524
TX	TARRANT	TX4390689.00	TAD LELAND RIZER ET UX	4/3/2008	TARRANT	D208157510
TX	TARRANT	TX4390690.00	JAMES GREGORY FONTENOT	11/15/2007	TARRANT	D208086893
TX	TARRANT	TX4390691.00	HEATHER M CROSETTI	11/15/2007	TARRANT	D208086944
TX	TARRANT	TX4390692.00	SHANNON R PRESLEY	11/15/2007	TARRANT	D208086888
TX	TARRANT	TX4390693.00	BRENDA L NEAGLE	11/15/2007	TARRANT	D208086992
TX	TARRANT	TX4390694.00	DAVID HEBENSTREIT	11/15/2007	TARRANT	D208086910
TX	TARRANT	TX4390695.00	RASEC BARRIENTOS	11/15/2007	TARRANT	D208157458
TX	TARRANT	TX4390696.00	ATHENA L LOGAN	11/15/2007	TARRANT	D208086902
TX	TARRANT	TX4390697.00	H A MILLS ET UX	11/15/2007	TARRANT	D208086914
TX	TARRANT	TX4390698.00	LIZANDRO NARANJO ET UX	11/15/2007	TARRANT	D208086906
TX	TARRANT	TX4390699.00	CHRISTOPHER WILLIAMSON ET	11/15/2007	TARRANT	D208086885
TX	TARRANT	TX4390700.00	RUDY B ENCINAS ET UX	11/15/2007	TARRANT	D208086939
TX	TARRANT	TX4390701.00	PATRICK SCOTT CASTINE ET U	11/15/2007	TARRANT	D208086947
TX	TARRANT	TX4390702.00	JEFFREY A VOGEL ET UX	11/15/2007	TARRANT	D208086942
TX	TARRANT	TX4390703.00	SUNNY YOUNG ET AL	11/15/2007	TARRANT	D208086891
TX	TARRANT	TX4390704.00	DENISE R KENNEDY	2/7/2008	TARRANT	D208086962
TX	TARRANT	TX4390705.00	MICHAEL A BRANDENBURGH ET	11/15/2007	TARRANT	D208086924
TX	TARRANT	TX4390706.00	LESLIE R NICAISE JR	11/15/2007	TARRANT	D208086901
TX	TARRANT	TX4390707.00	REBECCA F BURTON	11/15/2007	TARRANT	D208086985

Exhibit A, Page 11

3230471v2

PORTIONS OF THIS EXHIBIT DENOTED WITH THREE ASTERISKS (***) HAVE BEEN OMITTED PURSUANT TO A REQUEST FOR CONFIDENTIAL TREATMENT

TX	TARRANT	TX4390708.00	MICHELE R STYKEL	2/7/2008	TARRANT	D208086956
TX	TARRANT	TX4390709.00	JEFFREY GODWIN ET AL	2/7/2008	TARRANT	D208086964
TX	TARRANT	TX4390710.00	JAMES D LOVE ET UX	11/15/2007	TARRANT	D208086929
TX	TARRANT	TX4390711.00	MARC SANTINI ET UX	2/7/2008	TARRANT	D208157456
TX	TARRANT	TX4390712.00	MARK A PIERCE ET UX	2/7/2008	TARRANT	D208086961
TX	TARRANT	TX4390713.00	DANIEL T ROBISON ET UX	11/15/2007	TARRANT	D208086970
TX	TARRANT	TX4390714.00	JOHN R GOOLSBY ET UX	2/7/2008	TARRANT	D208086977
TX	TARRANT	TX4390716.00	RACHAEL D ROURE	4/3/2008	TARRANT	D208157485
TX	TARRANT	TX4390718.00	SYED ATHER IMAM	4/3/2008	TARRANT	D208157514
TX	TARRANT	TX4390719.00	OMAR RODRIGUEZ	4/3/2008	TARRANT	D208157501
TX	TARRANT	TX4390720.00	FRANSISCO A COVARRUBIAS	4/3/2008	TARRANT	D208157526
TX	TARRANT	TX4390721.00	GABRIEL GUZMAN	4/3/2008	TARRANT	D208157486
TX	TARRANT	TX4390722.00	ERIC D WATERS	4/3/2008	TARRANT	D208157463
TX	TARRANT	TX4390723.00	DANIEL YUBETA JR ET UX	4/3/2008	TARRANT	D208157489
TX	TARRANT	TX4390724.00	RASHID J RAHAMAN ET UX	4/3/2008	TARRANT	D208157504
TX	TARRANT	TX4390725.00	RON S PETTY ET UX	4/3/2008	TARRANT	D208157473
TX	TARRANT	TX4390726.00	DAVID PAUL PALMER ET UX	4/3/2008	TARRANT	D208157531
TX	TARRANT	TX4390727.00	ALAN KOLMEIER ET UX	4/3/2008	TARRANT	D208157498
TX	TARRANT	TX4390734.00	B H LUSCOMBE & K A COVERLY	11/15/2007	TARRANT	D208086921
TX	TARRANT	TX4390735.00	JEFFREY R SMOUT ET UX	4/3/2008	TARRANT	D208157511
TX	TARRANT	TX4390736.00	CECILIA SALIMIAN	11/15/2007	TARRANT	D208086892
TX	TARRANT	TX4390737.00	TED G ELLIS ET UX	11/15/2007	TARRANT	D208086934
TX	TARRANT	TX4390738.00	JEFFERY M MILLER ET UX	11/15/2007	TARRANT	D208086991
TX	TARRANT	TX4390739.00	KEVIN KUDRNA	4/3/2008	TARRANT	D208157528
TX	TARRANT	TX4390740.00	WILLIAM CLARKE	11/15/2007	TARRANT	D208086912
TX	TARRANT	TX4390741.00	DARREN KEITH MILLER ET UX	11/15/2007	TARRANT	D208086990
TX	TARRANT	TX4390742.00	RAMON H GALLO ET UX	11/15/2007	TARRANT	D208086976
TX	TARRANT	TX4390743.00	SHADAWN S BROWN	4/3/2008	TARRANT	D208157513
TX	TARRANT	TX4390744.00	DIMONE MEYA ET UX	4/3/2008	TARRANT	D208157516
TX	TARRANT	TX4390745.00	JAVIER RODRIGUEZ	4/3/2008	TARRANT	D208157462
TX	TARRANT	TX4390746.00	JULIO SOLIS ET UX	2/7/2008	TARRANT	D208086966
TX	TARRANT	TX4390747.00	JACOB D WEST	11/15/2007	TARRANT	D208086923
TX	TARRANT	TX4390748.00	JEROME MORGAN ET UX	11/15/2007	TARRANT	D208086988
TX	TARRANT	TX4390749.00	ERIK A DECAIRE ET UX	11/15/2007	TARRANT	D208086949
TX	TARRANT	TX4390750.00	DEWAYNE WINROW ET UX	4/3/2008	TARRANT	D208157520

Exhibit A, Page 12

3230471v2

PORTIONS OF THIS EXHIBIT DENOTED WITH THREE ASTERISKS (***) HAVE BEEN OMITTED PURSUANT TO A REQUEST FOR CONFIDENTIAL TREATMENT

TX	TARRANT	TX4390751.00	SHERI H BALLARD	2/7/2008	TARRANT	D208086965
TX	TARRANT	TX4390752.00	DONNY PARSONS	4/3/2008	TARRANT	D208157515
TX	TARRANT	TX4390753.00	SUSAN FIRES ET VIR	4/3/2008	TARRANT	D208157506
TX	TARRANT	TX4390754.00	WILLIAM W CALLAHAN ET UX	4/3/2008	TARRANT	D208157503
TX	TARRANT	TX4390755.00	FIDEL MACIAS ET UX	10/24/2007	TARRANT	D208086978
TX	TARRANT	TX4390756.00	MICHELLE M BRASUELL-FIFE	2/7/2008	TARRANT	D208086968
TX	TARRANT	TX4390757.00	MATTHEW KENNEDY ET UX	11/15/2007	TARRANT	D208086894
TX	TARRANT	TX4390758.00	LAWRENCE ADAMS ET UX	11/15/2007	TARRANT	D208086903
TX	TARRANT	TX4390767.00	JOSE & JORGE MONTOYA	4/3/2008	TARRANT	D208157481
TX	TARRANT	TX4390768.00	NAOMI PEASE ET VIR	11/15/2007	TARRANT	D208086916
TX	TARRANT	TX4390769.00	JAMES A GRICE ET UX	11/15/2007	TARRANT	D208086987
TX	TARRANT	TX4390770.00	LEISHA & CLIFTON SHELTON	4/3/2008	TARRANT	D208157468
TX	TARRANT	TX4390771.00	ROBERT KNOWLTON ET UX	2/7/2008	TARRANT	D208086981
TX	TARRANT	TX4390772.00	SUSAN HORD ACREY ET VIR	7/25/2001	TARRANT	D201249809
TX	TARRANT	TX4390773.00	KENNER REALTY CORPORATION	2/7/2008	TARRANT	D208086994
TX	TARRANT	TX4390774.00	SHERMAN & AMY TRYON	4/3/2008	TARRANT	D208157523
TX	TARRANT	TX4390775.00	THOMAS AND DEBORAH WALSH	11/15/2007	TARRANT	D208086943
TX	TARRANT	TX4390776.00	JEFFREY & CONNIE JOHNSON	11/15/2007	TARRANT	D208086937
TX	TARRANT	TX4390777.00	DANIEL & AMANDA RAWLS	4/3/2008	TARRANT	D208157522
TX	TARRANT	TX4390778.00	RONALD SLONAKER ET UX	4/3/2008	TARRANT	D208157512
TX	TARRANT	TX4390779.00	BRANDY & DAVID GREEN	11/15/2007	TARRANT	D208086915
TX	TARRANT	TX4390780.00	CARLOS CARBALLO	4/3/2008	TARRANT	D208157500
TX	TARRANT	TX4390781.00	JOSHUA & KACIE CROWDER	4/3/2008	TARRANT	D208157519
TX	TARRANT	TX4390782.00	ARLENE & STEVE SARK	11/15/2007	TARRANT	D208086897
TX	TARRANT	TX4390783.00	BRANDON & STACY BEARD	11/15/2007	TARRANT	D208086993
TX	TARRANT	TX4390784.00	JON R CREIGHTON	2/7/2008	TARRANT	D208157454
TX	TARRANT	TX4390786.00	WILLIAM JOSEPH TUCKER ET U	12/4/2008	TARRANT	D208461225
TX	TARRANT	TX4390788.00	K GILL & KENDRA WALKER	11/15/2007	TARRANT	D208086938
TX	TARRANT	TX4390789.00	VINCENT MAGANA ET UX	4/3/2008	TARRANT	D208157483
TX	TARRANT	TX4390790.00	KEVIN L KLOIBER ET UX	4/3/2008	TARRANT	D208157472
TX	TARRANT	TX4390791.00	COREY DON CHAMBERS	4/3/2008	TARRANT	D208157471
TX	TARRANT	TX4390793.00	EMMA M BREWER TURPEN ET AL	3/7/2003	TARRANT	D203145423
TX	TARRANT	TX4390793.00	EMMA M BREWER TURPEN ET AL	3/7/2003
TX	TARRANT	TX4390793.00	EMMA M BREWER TURPEN ET AL	3/7/2003		D203145423
TX	TARRANT	TX4390793.00	EMMA M BREWER TURPEN ET AL	3/7/2003

Exhibit A, Page 13

3230471v2

PORTIONS OF THIS EXHIBIT DENOTED WITH THREE ASTERISKS (***) HAVE BEEN OMITTED PURSUANT TO A REQUEST FOR CONFIDENTIAL TREATMENT

TX	TARRANT	TX4390793.00	EMMA M BREWER TURPEN ET AL	3/7/2003
TX	TARRANT	TX4390793.00	EMMA M BREWER TURPEN ET AL	3/7/2003
TX	TARRANT	TX4390793.00	EMMA M BREWER TURPEN ET AL	3/7/2003
TX	TARRANT	TX4390793.00	EMMA M BREWER TURPEN ET AL	3/7/2003
TX	TARRANT	TX4390793.00	EMMA M BREWER TURPEN ET AL	3/7/2003
TX	TARRANT	TX4390817.00	JAMES KENNETH WIGGINS ET U	7/25/2001	TARRANT	D201249811
TX	TARRANT	TX4390825.00	EUGENE PHILIP BURTNER ET A	7/1/2008	TARRANT	D208268485
TX	TARRANT	TX4390826.00	DONALD L HUDGINS JR ET AL	5/10/2008	TARRANT	Duplicate Original D208191991
TX	TARRANT	TX4390826.00	DONALD L HUDGINS JR ET AL	5/10/2008	TARRANT	D208420204
TX	TARRANT	TX4390828.01	PHILLIP K SOTEL 2000 TRUST	8/5/2002	TARRANT	D202326159
TX	TARRANT	TX4390828.02	FRANCES L CLARK	8/5/2002	TARRANT	D203023488
TX	TARRANT	TX4390847.00	FREDERIK FLOREN TRUSTEE	3/3/2003	TARRANT	D203103742
TX	TARRANT	TX4390847.00	FREDERIK FLOREN TRUSTEE	3/3/2003
TX	TARRANT	TX4390848.00	DAVID TOM MCPHERSON ET UX	4/28/2008	TARRANT	D208191989
TX	TARRANT	TX4390850.00	KENNETH W BRADLEY ET UX	5/8/2008	TARRANT	D208191988
TX	TARRANT	TX4390852.00	WILLIAM & INA B JAMESON REV TR	10/24/2002	TARRANT	D203145442
TX	TARRANT	TX4390852.00	WILLIAM & INA B JAMESON REV TR	10/24/2002
TX	TARRANT	TX4390852.00	WILLIAM & INA B JAMESON REV TR	10/24/2002
TX	TARRANT	TX4390877.00	ALLIANCE HOTEL II LTD	3/17/2009	TARRANT	D209128427
TX	TARRANT	TX4390878.00	SAGAMORE-FORT WORTH LP	3/17/2009	TARRANT	D209128428
TX	TARRANT	TX4390916.99	ALICE LAVON BREWER	6/29/2009	TARRANT	D209177830
TX	TARRANT	TX4390920.99	SUSAN ACREY	8/31/2009	TARRANT	D209235059
TX	TARRANT AND DENTON	TX4390921.00	MOUNT OLIVET CEMETERY ASSN	8/3/2009	TARRANT	D209208077
TX	TARRANT AND DENTON	TX4390921.00	MOUNT OLIVET CEMETERY ASSN	8/3/2009	DENTON	2009-95113
TX	TARRANT	TX4390923.00	ST TX MF-110200	7/14/2009	TARRANT	D209202877
TX	TARRANT	TX4390958.99	STEVEN W NORTHINGTON	11/10/2009	TARRANT	D209303332
TX	TARRANT	TX4390960.00	TODD FAMILY LIVING TRUST	12/2/2009	TARRANT	D209323848
TX	TARRANT	TX4390961.00	PAUL WILBANKS ET UX	12/2/2009	TARRANT	D209323847
TX	TARRANT	TX4390964.00	JOHN C MCGAUGH	12/14/2009	TARRANT	D210016299
TX	TARRANT	TX4390965.00	KEVIN A LEE ET UX	12/14/2009	TARRANT	D210016300

Exhibit A, Page 14

3230471v2

PORTIONS OF THIS EXHIBIT DENOTED WITH THREE ASTERISKS (***) HAVE BEEN OMITTED PURSUANT TO A REQUEST FOR CONFIDENTIAL TREATMENT

TX	TARRANT	TX4390966.00	MARIELLA E UGAZ ET VIR	12/14/2009	TARRANT			D210016301
TX	TARRANT	TX4390971.00	CHAD A WHITE ET UX	12/7/2009	TARRANT			D210016302
TX	TARRANT	TX4390978.00	ST TX 110640	3/23/2010	TARRANT			D210092561
TX	TARRANT	TX4390983.01	PCP LOST CREEK RANCH NORTH	2/1/2010	TARRANT			D210107250
TX	TARRANT	TX4390983.02	D L HUDGINS JR	2/1/2010	TARRANT			D210107249
TX	TARRANT	TX4390984.00	SCOTT GRAZER ET UX	2/12/2010	TARRANT			D210042820
TX	TARRANT	TX4390987.00	ODETTE NGOIE TSHISEKEDI ET AL	2/12/2010	TARRANT			D210042817
TX	TARRANT	TX4390988.00	LOST SPURS DEVELOPMENT INC	2/1/2010	TARRANT			D210107248
TX	TARRANT	TX4390999.00	VIRGINIA ARMENDARIZ	3/24/2010	TARRANT			D210092557
TX	TARRANT	TX4391000.00	JAIMARIE SANTOS-ROMAN ET VIR	3/15/2010	TARRANT			D210092558
TX	TARRANT	TX4391001.00	TARE L DURR ET VIR	3/24/2010	TARRANT			D210092559
TX	TARRANT	TX4391007.00	RICHARD BARBER ET UX	3/25/2010	TARRANT			D210078911
TX	TARRANT	TX4391011.00	MICHAEL K THURMAN ET UX	4/15/2010	TARRANT			D210092560
TX	TARRANT	TX4391013.00	JEAN PHILLIPE ISSOM ET UX	4/23/2010	TARRANT			D210107278
TX	TARRANT	TX4391014.00	AMIR HONARDAR	4/26/2010	TARRANT			D210123322
TX	TARRANT	TX4391016.00	NICOLE OLBRICH MEEK ET VIR	5/4/2010	TARRANT			D210107277
TX	TARRANT	TX4391019.00	TONY COUGHLIN ET UX	4/12/2010	TARRANT			D210123323
TX	TARRANT	TX4391025.01	LONZO E MEDLIN TRUST	8/29/2001	TARRANT			D201211727
TX	TARRANT	TX4391025.01	LONZO E MEDLIN TRUST	8/29/2001
TX	TARRANT	TX4391025.02	FLEISCHAKER MINERAL CO	1/16/2001	TARRANT			D201277370
TX	TARRANT	TX4391025.02	FLEISCHAKER MINERAL CO	1/16/2001
TX	TARRANT	TX4391025.03	FLEISCHAKER MINERAL CO LLC	1/15/2010	TARRANT			D210042824
TX	TARRANT	TX4391025.04	LANGSTON MINERAL ET AL	4/1/2010	TARRANT			D210155884
TX	TARRANT	TX4391026.01	MARGARET R SCHLUTER	9/13/2001	TARRANT	15268	73	D201284943
TX	TARRANT	TX4391026.01	MARGARET R SCHLUTER	9/13/2001
TX	TARRANT	TX4391026.02	REYNOLDS CHAR TRUST	11/15/2001	TARRANT	15281	430	D201291010
TX	TARRANT	TX4391026.02	REYNOLDS CHAR TRUST	11/15/2001
TX	TARRANT	TX4391026.03	N LILLIAN & S REYNOLDS CHAR TR	4/1/2010	TARRANT			D210199520
TX	TARRANT	TX4391026.04	MARGARET R HUGHES	4/1/2010	TARRANT			D210155885
TX	TARRANT	TX4391027.00	VIVIANE L SCHMUTZLER ET VIR	6/9/2010	TARRANT			D210139574
TX	TARRANT	TX4391028.00	BRANTON K LOEWEN ET UX	5/18/2010	TARRANT			D210139575
TX	TARRANT	TX4391038.00	B-TEX MINERALS LP	8/9/2010	TARRANT			D210193026
TX	TARRANT	TX4391041.00	NORTEX MINERALS LP	8/4/2010	TARRANT			D210217434
TX	TARRANT	TX4391043.00	AMBER A BOS	7/28/2010	TARRANT			D210201300

Exhibit A, Page 15

3230471v2

PORTIONS OF THIS EXHIBIT DENOTED WITH THREE ASTERISKS (***) HAVE BEEN OMITTED PURSUANT TO A REQUEST FOR CONFIDENTIAL TREATMENT

TX	TARRANT	TX4391045.00	DARREN W JOHNSTON	6/23/2010	TARRANT			D210211172
TX	TARRANT	TX4391046.00	KELLY WEBBER	8/6/2010	TARRANT			D210201298
TX	TARRANT	TX4391047.00	MITCHELL TODD	8/16/2010	TARRANT			D210211173
TX	TARRANT	TX4391048.00	ROBERT KYLE ROGERS ET UX	8/16/2010	TARRANT			D210206464
TX	TARRANT	TX4391049.00	TINA MORALES	8/16/2010	TARRANT			D210201299
TX	TARRANT	TX4391053.00	ZHI WANG & XIAPING QU	8/18/2010	TARRANT			D210206465
TX	TARRANT	TX4391061.00	SHENG-FANG HUANG ET UX	8/31/2010	TARRANT			D210220317
TX	TARRANT	TX4391063.00	ANG ANDREW OUM	8/31/2010	TARRANT			D210220316
TX	TARRANT	TX4391067.00	ERIC W BURISKY	8/16/2010	TARRANT			D210229109
TX	TARRANT	TX4391270.00	THOMAS E RADELL ET UX	4/19/2011	TARRANT			D211099720
TX	TARRANT	TX4391301.00	XIANPING QU & ZHI WANG	9/14/2011	TARRANT			D211226008
TX	TARRANT	TX4391311.00	NORTEX MINERALS LP	10/12/2011	TARRANT			D211253270
TX	TARRANT	TX4391364.01	EAGLE FARMS INC	4/21/2014	TARRANT			D214084784
TX	TARRANT	TX4391365.01	ROY & EMMA FREER INDIV & TREES	5/13/2014	TARRANT			D214132771
TX	TARRANT	TX4391367.00	LOTTIE BARTON JOHNSON	8/12/1985	TARRANT	8306	1547
TX	TARRANT	TX1210031.33	ROGER DALE JORDAN ET UX	9/24/2014	TARRANT			D214216579
TX	TARRANT	TX1210031.42	JIMMY CHARLES MOSLEY ET UX	10/24/2014	TARRANT			D214256084
TX	TARRANT	TX1210031.43	JEFFREY SCOTT CORNELIUS ET UX	11/10/2014	TARRANT			D214256086
TX	TARRANT	TX1210031.44	DONALD R STARNES ET UX	10/21/2014	TARRANT			D214275918
TX	TARRANT	TX1210031.45	TAMELA L GILLHAM	7/30/2014	TARRANT			D214275917
TX	TARRANT	TX1210031.50	GARY D LARIMER ET UX	12/9/2014	TARRANT			D215002808
TX	TARRANT	TX1210031.51	PHILIP R BOYD	10/17/2014	TARRANT			D215008926
TX	TARRANT	TX1210031.61	FRANK ROSNER ET UX	3/3/2015	TARRANT			D215055162
TX	TARRANT	TX1210031.62	PHILLIP WARREN JOHNSON	3/5/2015	TARRANT			D215068008
TX	TARRANT	TX1210031.63	RODNEY A NESBITT ET UX	7/30/2014	TARRANT			D215118279
TX	DENTON AND TARRANT	TX1210001.00	NORTEX MINERALS LP	12/1/2006	DENTON			2007-30172
TX	DENTON AND TARRANT	TX1210001.00	NORTEX MINERALS LP	12/1/2006
TX	DENTON AND TARRANT	TX1210002.00	NORTEX MINERALS LP	12/15/2005	DENTON			2006-35282
TX	DENTON AND TARRANT	TX1210002.00	NORTEX MINERALS LP	12/15/2005
TX	DENTON AND TARRANT	TX1210003.00	NORTEX MINERALS LP	12/31/2005	DENTON			2006-72364

Exhibit A, Page 16

3230471v2

PORTIONS OF THIS EXHIBIT DENOTED WITH THREE ASTERISKS (***) HAVE BEEN OMITTED PURSUANT TO A REQUEST FOR CONFIDENTIAL TREATMENT

TX	DENTON AND TARRANT	TX1210003.00	NORTEX MINERALS LP	12/31/2005
TX	DENTON AND TARRANT	TX1210004.00	NORTEX MINERALS LP	1/1/2005	DENTON			2005-35383
TX	DENTON AND TARRANT	TX1210004.00	NORTEX MINERALS LP	1/1/2005
TX	DENTON AND TARRANT	TX1210005.00	NORTEX MINERALS LP	5/1/2003	DENTON			2004-124550
TX	DENTON AND TARRANT	TX1210005.00	NORTEX MINERALS LP		TARRANT			D203315430
TX	DENTON AND TARRANT	TX1210005.00	NORTEX MINERALS LP	5/1/2003
TX	DENTON AND TARRANT	TX1210005.00	NORTEX MINERALS LP
TX	DENTON AND TARRANT	TX1210005.00	NORTEX MINERALS LP
TX	DENTON AND TARRANT	TX1210005.00	NORTEX MINERALS LP	5/1/2003
TX	DENTON AND TARRANT	TX1210005.00	NORTEX MINERALS LP
TX	DENTON	TX1210006.00	PETERSON FAMILY TRUST ETAL	11/7/2006	DENTON			2006-137384
TX	DENTON	TX1210007.00	PATTERSON LOGISTICS SVC	8/20/2007	DENTON			2007-108522
TX	DENTON AND TARRANT	TX1210008.01	NORTEX MINERALS LP	4/30/2007	DENTON			2007-69391
TX	DENTON AND TARRANT	TX1210008.01	NORTEX MINERALS LP	4/30/2007
TX	DENTON	TX1210008.02	LEOLA W HUGG CHARITABLE TR	10/17/2006	DENTON			2006-141646
TX	DENTON AND TARRANT	TX1210010.01	NORTEX MINERALS LP	1/1/2005	DENTON			2005-35383
TX	DENTON AND TARRANT	TX1210010.01	NORTEX MINERALS LP	1/1/2005
TX	DENTON AND TARRANT	TX1210011.01	WAUNITA L CLARK	8/12/2001	DENTON	4931	1803	101800
TX	DENTON AND TARRANT	TX1210011.01	WAUNITA L CLARK	8/12/2001	TARRANT			D203174562
TX	DENTON AND TARRANT	TX1210011.01	WAUNITA L CLARK	8/12/2001
TX	DENTON AND TARRANT	TX1210011.01	WAUNITA L CLARK	8/12/2001
TX	DENTON AND TARRANT	TX1210011.01	WAUNITA L CLARK	8/12/2001

Exhibit A, Page 17

3230471v2

PORTIONS OF THIS EXHIBIT DENOTED WITH THREE ASTERISKS (***) HAVE BEEN OMITTED PURSUANT TO A REQUEST FOR CONFIDENTIAL TREATMENT

	DENTON AND TARRANT	TX1210011.01	WAUNITA L CLARK	8/12/2001
TX	DENTON AND TARRANT	TX1210011.02	LAURA BETH BRINKER	8/12/2001	DENTON	4931	1807	101801
TX	DENTON AND TARRANT	TX1210011.02	LAURA BETH BRINKER	8/12/2001	TARRANT			D203174564
TX	DENTON AND TARRANT	TX1210011.02	LAURA BETH BRINKER	8/12/2001
TX	DENTON AND TARRANT	TX1210011.02	LAURA BETH BRINKER	8/12/2001
TX	DENTON AND TARRANT	TX1210011.02	LAURA BETH BRINKER	8/12/2001
TX	DENTON AND TARRANT	TX1210011.02	LAURA BETH BRINKER	8/12/2001
TX	DENTON AND TARRANT	TX1210011.03	JACK CROWLEY ET AL	8/27/2001	DENTON	4931	1812	101802
TX	DENTON AND TARRANT	TX1210011.03	JACK CROWLEY ET AL	8/27/2001	TARRANT			D203174561
TX	DENTON AND TARRANT	TX1210011.03	JACK CROWLEY ET AL	8/27/2001
TX	DENTON AND TARRANT	TX1210011.03	JACK CROWLEY ET AL	8/27/2001
TX	DENTON AND TARRANT	TX1210011.03	JACK CROWLEY ET AL	8/27/2001
TX	DENTON AND TARRANT	TX1210011.03	JACK CROWLEY ET AL	8/27/2001
TX	DENTON AND TARRANT	TX1210011.03	JACK CROWLEY ET AL	8/27/2001
TX	DENTON AND TARRANT	TX1210011.03	JACK CROWLEY ET AL	8/27/2001
TX	DENTON AND TARRANT	TX1210012.01	DR WELLS O STEPHENS EST	12/17/2001	DENTON	5000	1164	4043
TX	DENTON AND TARRANT	TX1210012.01	DR WELLS O STEPHENS EST	12/17/2001	TARRANT			D202037586
TX	DENTON AND TARRANT	TX1210012.02	DR C B KENDALL EST	12/17/2001	DENTON	5000	1169	4044
TX	DENTON AND TARRANT	TX1210012.02	DR C B KENDALL EST	12/17/2001	TARRANT			D202037587
TX	DENTON	TX1210016.00	KENDRA STEPHENS ET AL	1/15/2008	DENTON			2008-27701
TX	DENTON	TX1210017.00	GLENN HYDE ET AL	4/5/2002	DENTON	5249	1757	4574
TX	DENTON	TX1210018.01	THE PROSPECT COMPANY	1/30/2009	DENTON			2009-19205

Exhibit A, Page 18

3230471v2

PORTIONS OF THIS EXHIBIT DENOTED WITH THREE ASTERISKS (***) HAVE BEEN OMITTED PURSUANT TO A REQUEST FOR CONFIDENTIAL TREATMENT

TX	DENTON	TX1210018.02	PETRUS INVESTMENT LP	9/15/2009	DENTON			2010-37198
TX	DENTON	TX1210018.04	TEXAS MOTOR SPEEDWAY INC	12/20/2011	DENTON			2012-25549
TX	DENTON	TX1210019.01	NORTH DALLAS BROKERS INC	5/5/2002	DENTON	5099	1112	69050
TX	DENTON	TX1210020.00	DOROTHY GEBERT	10/12/2001	DENTON	4988	5	137605
TX	DENTON	TX1210021.00	BUCHANAN PARTNERS LTD	11/1/2001	DENTON	4964	1854
TX	DENTON	TX1210021.00	BUCHANAN PARTNERS LTD	11/1/2001
TX	DENTON	TX1210021.00	BUCHANAN PARTNERS LTD	11/1/2001
TX	DENTON	TX1210023.00	LEWAYNE PETERSON TR ET AL	7/31/2006	DENTON			2006-94361
TX	DENTON AND TARRANT	TX1210024.01	NORTEX MINERALS LP	8/15/2005	DENTON			2006-21810
TX	DENTON AND TARRANT	TX1210024.01	NORTEX MINERALS LP	8/15/2005
TX	DENTON AND TARRANT	TX1210026.01	PBBM NORTHLAKE LTD	3/2/2009	DENTON			2009-60422
TX	DENTON AND TARRANT	TX1210026.01	PBBM NORTHLAKE LTD	3/2/2009
TX	DENTON AND TARRANT	TX1210026.01	PBBM NORTHLAKE LTD	3/2/2009
TX	DENTON AND TARRANT	TX1210026.01	PBBM NORTHLAKE LTD	3/2/2009
TX	DENTON	TX1210026.02	DEVON ENERGY PRODUCTION COMPANY LP	6/4/2012	DENTON			2012-68882
TX	DENTON	TX1210029.00	PETRUS INVESTMENT LP	9/15/2009	DENTON			2010-37199
TX	DENTON AND TARRANT	TX1210031.13	LUMINANT MINERAL DEVELOPMENT	3/2/2010	DENTON			2010-22559
TX	DENTON AND TARRANT	TX1210031.13	LUMINANT MINERAL DEVELOPMENT	3/2/2010	TARRANT			D210047137
TX	DENTON AND TARRANT	TX1210031.14	JOHN PORTER FARMS INC	4/21/2014	DENTON			2014-41356
TX	DENTON AND TARRANT	TX1210031.14	JOHN PORTER FARMS INC	4/21/2014	TARRANT			D214084785
TX	DENTON AND TARRANT	TX1210031.15	BOB CATES ET UX	4/23/2014	DENTON			2014-41354
TX	DENTON AND TARRANT	TX1210031.15	BOB CATES ET UX	4/23/2014	TARRANT			D214084785
TX	DENTON AND TARRANT	TX1210031.16	JOE CATES ET UX	4/23/2014	DENTON			2014-41355
TX	DENTON	TX1210031.17	RUSSELL C HOLLINGSWORTH ET UX	5/6/2014	DENTON			2014-49256
TX	DENTON	TX1210031.18	CARL BRASWELL ET UX	5/1/2014	DENTON			2014-41359

Exhibit A, Page 19

3230471v2

PORTIONS OF THIS EXHIBIT DENOTED WITH THREE ASTERISKS (***) HAVE BEEN OMITTED PURSUANT TO A REQUEST FOR CONFIDENTIAL TREATMENT

TX	DENTON	TX1210031.19	GRANT T DOSTERT ET UX	4/24/2014	DENTON	2014-49255
TX	DENTON AND TARRANT	TX1210031.20	PAUL D COPENHAVER JR ET UX	5/12/2014	DENTON	2014-49254
TX	DENTON	TX1210031.22	BARRY LEMONS ET UX	6/5/2014	DENTON	2014-77321
TX	DENTON	TX1210031.23	JAMES F HUNTER	6/11/2014	DENTON	2014-61289
TX	DENTON	TX1210031.24	CLYDE E WALL ET UX	7/7/2014	DENTON	2014-73371
TX	DENTON	TX1210031.25	DARIN G WINGER ET UX	7/9/2014	DENTON	2014-73372
TX	DENTON	TX1210031.26	PAUL J FLEURY ET UX	7/17/2014	DENTON	2014-77320
TX	DENTON AND TARRANT	TX1210031.27	JOHN MURLEY	7/24/2014	DENTON	2014-82676
TX	DENTON AND TARRANT	TX1210031.27	JOHN MURLEY	7/24/2014	TARRANT	D215142691
TX	DENTON AND TARRANT	TX1210031.28	SUE WORKS	5/16/2014	DENTON	2014-61290
TX	DENTON AND TARRANT	TX1210031.28	SUE WORKS	5/16/2014	TARRANT	D214132772
TX	DENTON	TX1210031.29	MARILYN L BOEMER	8/13/2014	TARRANT	D214195143
TX	DENTON AND TARRANT	TX1210031.30	PAUL A PINSON ET UX	8/13/2014	TARRANT	D214195144
TX	TARRANT	TX1210031.31	DEBORAH L FLORES	8/13/2014	TARRANT	D214195145
TX	DENTON AND TARRANT	TX1210031.32	WILLIAM A KIRK	8/18/2014	DENTON	2014-100907
TX	DENTON AND TARRANT	TX1210031.32	WILLIAM A KIRK	8/18/2014	TARRANT	D214195142
TX	DENTON	TX1210031.34	MARK ALLEN HUFF	8/9/2014	DENTON	2014-100906
TX	DENTON	TX1210031.35	CHAD DAVID REITHMEIER ET UX	8/29/2014	DENTON	2014-100905
TX	DENTON AND TARRANT	TX1210031.36	RICHARD N BROWN ET UX	6/26/2014	DENTON	2014-109197
TX	DENTON AND TARRANT	TX1210031.36	RICHARD N BROWN ET UX	6/26/2014	TARRANT	D214225480
TX	DENTON AND TARRANT	TX1210031.37	PAUL DON CRUSE ET UX	10/8/2014	DENTON	2014-109196
TX	DENTON AND TARRANT	TX1210031.37	PAUL DON CRUSE ET UX		TARRANT	D214225481
TX	DENTON AND TARRANT	TX1210031.39	KENNETH MILLER	10/16/2014	DENTON	2014-122345
TX	DENTON AND TARRANT	TX1210031.39	KENNETH MILLER	10/16/2014	TARRANT	D214256085
TX	DENTON	TX1210031.40	ROBERTA MARIE CRUSE	10/8/2014	DENTON	2014-109195

Exhibit A, Page 20

3230471v2

PORTIONS OF THIS EXHIBIT DENOTED WITH THREE ASTERISKS (***) HAVE BEEN OMITTED PURSUANT TO A REQUEST FOR CONFIDENTIAL TREATMENT

TX	DENTON AND TARRANT	TX1210031.41	LARRY CARSON TIDWELL ET UX	11/6/2014	DENTON	2015-1219
TX	DENTON AND TARRANT	TX1210031.41	LARRY CARSON TIDWELL ET UX	11/6/2014	TARRANT	D214275922
TX	DENTON AND TARRANT	TX1210031.46	RAYA NEVEEN REDDY ET UX	12/10/2014	DENTON	2015-1217
TX	DENTON AND TARRANT	TX1210031.46	RAYA NEVEEN REDDY ET UX	12/10/2014	TARRANT	D214275920
TX	DENTON	TX1210031.47	JOHNNY G GRACE ET UX	10/29/2014	DENTON	2015-1222
TX	TARRANT	TX1210031.48	MELISSA M TAYLOR ET VIR	11/11/2014	TARRANT	D214275921
TX	DENTON	TX1210031.49	JAMES R SOWELL ET UX	9/2/2014	DENTON	2015-1220
TX	DENTON AND TARRANT	TX1210031.52	JOHN T MASON	8/25/2014	DENTON	2015-8218
TX	DENTON AND TARRANT	TX1210031.52	JOHN T MASON	8/25/2014	TARRANT	D215013068
TX	DENTON AND TARRANT	TX1210031.53	SHERRY BUGG	10/24/2014	DENTON	2015-8217
TX	DENTON AND TARRANT	TX1210031.53	SHERRY BUGG	10/24/2014	TARRANT	D215013067
TX	DENTON AND TARRANT	TX1210031.56	JAMES R HAIRE ET UX	12/18/2014	DENTON	2015-14690
TX	DENTON AND TARRANT	TX1210031.56	JAMES R HAIRE ET UX		TARRANT	D215026331
TX	DENTON AND TARRANT	TX1210031.57	DALE GLEN & STELLA MARIE EDELMAN	1/21/2015	DENTON	2015-14688
TX	DENTON AND TARRANT	TX1210031.57	DALE GLEN & STELLA MARIE EDELMAN	1/21/2015	TARRANT	D215046447
TX	DENTON	TX1210031.58	RANDELL M DAY	1/6/2015	DENTON	2015-14689
TX	DENTON AND TARRANT	TX1210031.59	KEVIN SIMMONS	2/5/2015	DENTON	2015-26717
	DENTON AND TARRANT	TX1210031.59	KEVIN SIMMONS		TARRANT	D215046448
TX	DENTON AND TARRANT	TX1210031.60	ANGELA DAONNE RAWIE	8/19/2014	DENTON	2015-26718
	DENTON AND TARRANT	TX1210031.60	ANGELA DAONNE RAWIE		TARRANT	D215052665
TX	DENTON	TX1210031.64	CARRIE RENE RENDON	11/13/2014	DENTON	2015-60638
TX	DENTON	TX1210031.66	TIFFANY D MAYES ET AL	6/9/2015	DENTON	2015-117487
TX	DENTON	TX1210031.67	JERRY L SMART ET UX	12/5/2015	DENTON	PENDING
TX	DENTON	TX1210031.68	WILLIAM G BAKER	12/3/2015	DENTON	PENDING

Exhibit A, Page 21

3230471v2

PORTIONS OF THIS EXHIBIT DENOTED WITH THREE ASTERISKS (***) HAVE BEEN OMITTED PURSUANT TO A REQUEST FOR CONFIDENTIAL TREATMENT

TX	DENTON	TX1210031.69	JAMES E BROOME ET UX	12/3/2015	DENTON	PENDING
TX	DENTON	TX1210031.70	RICHARD A CIAMPA ET UX	12/2/2015	DENTON	PENDING
TX	DENTON	TX1210031.71	JASBIR SIDHU ET UX	12/7/2015	DENTON	PENDING
TX	DENTON	TX1210031.72	GARY ALLEN MIRON ET UX	12/7/2015	DENTON	PENDING
TX	DENTON	TX1210031.73	MARCIA J WIETING	12/4/2015	DENTON	PENDING
TX	DENTON	TX1210039.02	A & C CATTLE COMPANY LLC	8/19/2014	DENTON	2014-90016
TX	DENTON	TX1210044.00	PETRUS INVESTMENT LP	8/4/2010	DENTON	2010-89083
TX	DENTON	TX1210048.01	INTEL CORPORATION	9/23/2010	DENTON	2010-98249
TX	DENTON	TX1210051.01	ALLIANCE AIRPORT AUTHORITY INC	5/3/2011	DENTON	2011-42422
TX	DENTON	TX1210051.01	ALLIANCE AIRPORT AUTHORITY INC
TX	DENTON	TX1210052.00	HOWARD PETERSON IRREVOC TR	5/4/2011	DENTON	2011-42421
TX	DENTON	TX1210056.99	INTEL CORPORATION	10/25/2011	DENTON	2011-103169
TX	DENTON	TX1210060.01	ROXANNE HARMONSON DOLPH	9/19/2011	DENTON	2011-90979
TX	DENTON	TX1210060.02	MARIE PETTY ETHRIDGE	9/20/2011	DENTON	2011-93491
TX	DENTON	TX1210060.03	PETER C HARMONSON III	9/19/2011	DENTON	2011-93493
TX	DENTON	TX1210060.04	BOBBY KIRK HARMONSON	9/19/2011	DENTON	2011-93492
TX	DENTON	TX1210060.05	DAVID L HARMONSON	9/19/2011	DENTON	2011-93494
TX	DENTON	TX1210060.06	PAULA H DUNCAN	9/19/2011	DENTON	2011-93495
TX	DENTON	TX1210060.07	LEE ANN THOMAS MILLER	9/29/2011	DENTON	2011-102938
TX	DENTON	TX1210060.08	RITA CARMA LEE DAVIS	9/22/2011	DENTON	2011-102941
TX	DENTON	TX1210060.09	CATHERINE LYNN THOMAS HAMILTON	9/29/2011	DENTON	2011-102940
TX	DENTON	TX1210060.10	DAVID EDWIN LEE	9/28/2011	DENTON	2011-102939
TX	DENTON	TX1210060.11	NONA LOIS LEE STONE	9/22/2011	DENTON	2011-102935
TX	DENTON	TX1210060.12	WILLIAM S SWAN	9/30/2011	DENTON	2011-102936
TX	DENTON	TX1210060.13	LINDA THOMAS	10/11/2011	DENTON	2011-102937
TX	DENTON	TX1210060.14	MELBA JEAN LEE KOVICS	9/22/2011	DENTON	2011-104265
TX	DENTON	TX1210060.15	ROBERT EARL LEE	9/22/2011	DENTON	2011-104264
TX	DENTON	TX1210060.16	ARLIN LEE	9/29/2011	DENTON	2011-104263
TX	DENTON	TX1210060.17	LESLIE JO BALTON	10/18/2011	DENTON	2011-106798
TX	DENTON	TX1210060.18	PERRY VAN MOORE	10/20/2011	DENTON	2011-106797
TX	DENTON	TX1210060.20	ROBERT BEAMS	10/20/2011	DENTON	2011-106796
TX	DENTON	TX1210060.21	BETTY BELLAMY	10/20/2011	DENTON	2011-106791
TX	DENTON	TX1210060.22	J RUSSELL BELLAMY	10/20/2011	DENTON	2011-106792

Exhibit A, Page 22

3230471v2

PORTIONS OF THIS EXHIBIT DENOTED WITH THREE ASTERISKS (***) HAVE BEEN OMITTED PURSUANT TO A REQUEST FOR CONFIDENTIAL TREATMENT

TX	DENTON	TX1210060.23	RODNEY L LEE	9/29/2011	DENTON	2011-106793
TX	DENTON	TX1210060.24	IDELLA L MCFARLEN	10/24/2011	DENTON	2011-110028
TX	DENTON	TX1210060.25	OTIS E SMITH	10/24/2011	DENTON	2011-106794
TX	DENTON	TX1210060.26	RKJR PROPERTIES LTD	11/18/2011	DENTON	2011-113741
TX	DENTON	TX1210060.27	ROBERT HUFF MITCHELL C TRUST	11/18/2011	DENTON	2011-113740
TX	DENTON	TX1210060.28	JEAN EVELYN MITCHELL C TRUST	11/18/2011	DENTON	2011-113739
TX	DENTON	TX1210060.29	JOHN E GIBSON	11/1/2011	DENTON	2011-110026
TX	DENTON	TX1210060.30	LINDA W COLLINS	10/20/2011	DENTON	2011-110027
TX	DENTON	TX1210060.31	STEVEN LEE THOMAS	10/25/2011	DENTON	2011-110029
TX	DENTON	TX1210060.32	SUE WOOLDRIDGE	10/20/2011	DENTON	2011-110031
TX	DENTON	TX1210060.33	JANE REYNOLDS	10/20/2011	DENTON	2011-110030
TX	DENTON	TX1210060.34	CAROLYN WEST	11/11/2011	DENTON	2011-113738
TX	DENTON	TX1210060.35	JACK E SMITH	11/7/2011	DENTON	2011-113743
TX	DENTON	TX1210060.36	STAN COMBEST ET UX	10/5/2011	DENTON	2011-113742
TX	DENTON	TX1210060.37	SHARON R VANDERGRIFT	11/17/2011	DENTON	2011-117400
TX	DENTON	TX1210060.38	CYNTHIA RAINEY YEWELL ET AL	12/13/2011	DENTON	2012-910
TX	DENTON	TX1210060.39	KENNETH WAYNE RAINEY	12/13/2011	DENTON	2012-909
TX	DENTON	TX1210060.40	JENNIFER R RAINEY ESTATE	12/13/2011	DENTON	2012-908
TX	DENTON	TX1210060.41	FW SPORTS AUTHORITY INC	12/20/2011	DENTON	2011-121883
TX	DENTON	TX1210060.42	THE PROSPECT COMPANY	11/10/2011	DENTON	2012-4688
TX	DENTON	TX1210060.43	FRANKIE JO LEE ROBBINS ET AL	2/15/2011	DENTON	2011-22216
TX	DENTON	TX1210060.44	CITY OF FORT WORTH	8/24/2012	DENTON	2012-108148
TX	DENTON	TX1210060.45	TEXAS MOTOR SPEEDWAY INC	3/7/2013	DENTON	2013-39639
TX	DENTON	TX1210060.46	ST TX MF-115929	11/5/2013	DENTON	2013-143751
TX	DENTON	TX1210060.47	MONTE CLAMPITT	6/27/2013	DENTON	2013-143747
TX	DENTON	TX1210060.48	MARK MCADAMS	7/9/2013	DENTON	2013-143749
TX	DENTON	TX1210060.49	MARCELLA P STRICKLAND	7/9/2013	DENTON	2013-143750
TX	DENTON	TX1210060.50	MARSHA A CRAWFORD	7/9/2013	DENTON	2013-143748
TX	DENTON	TX1210060.51	JAMES E PEPPER	7/9/2013	DENTON	2014-1197
TX	DENTON	TX1210060.52	BUCHANAN PARTNERS LTD	7/1/2014	DENTON	2014-73370
TX	DENTON	TX1210060.53	PETRUS INVESTMENT LP	4/22/2014	DENTON	2014-49248
TX	DENTON	TX1210066.01	LAHONDA JO PETERSON	5/12/2010	DENTON	2010-55825
TX	DENTON	TX1210066.01	LAHONDA JO PETERSON	5/12/2010
TX	DENTON	TX1210066.02	TRUETT WELDON PETERSON	5/12/2010	DENTON	2010-60220
TX	DENTON	TX1210066.02	TRUETT WELDON PETERSON

Exhibit A, Page 23

3230471v2

PORTIONS OF THIS EXHIBIT DENOTED WITH THREE ASTERISKS (***) HAVE BEEN OMITTED PURSUANT TO A REQUEST FOR CONFIDENTIAL TREATMENT

TX	DENTON	TX1210067.00	BLM TX NM-101032	9/1/1998	DENTON
TX	DENTON	TX1210069.00	GLORIA HAMMACK REV TRUST ET AL	6/1/2006	DENTON	2006-81898
TX	DENTON	TX1210071.00	ST TX MF-114704	1/8/2013	DENTON	2013-14110
TX	DENTON	TX1210072.01	NORTEX MINERALS LP	3/1/2013	DENTON	2013-21369
TX	DENTON	TX1210074.00	WILLIAMS QUALITY RENTAL LLC	8/5/2013	DENTON	2013-111254
TX	DENTON	TX1210075.00	AHMAD FAMILY PARTNERSHIP	1/9/2014	DENTON	2014-3716
TX	DENTON	TX1210079.00	RUSSELL E HALL ET UX	4/23/2014	DENTON	2014-41360
TX	DENTON	TX1210083.00	RAYMOND MICHAEL CHARLEY	12/3/2015	DENTON	PENDING
TX	DENTON AND TARRANT	TX4390481.00	NORTEX MINERALS LP	9/1/2005	DENTON	2008-51627
TX	DENTON AND TARRANT	TX4390481.00	NORTEX MINERALS LP	9/1/2005	TARRANT	D206181584
TX	DENTON AND TARRANT	TX4390481.00	NORTEX MINERALS LP	9/1/2005
TX	DENTON AND TARRANT	TX4390481.00	NORTEX MINERALS LP	9/1/2005
TX	DENTON AND TARRANT	TX4390481.00	NORTEX MINERALS LP	9/1/2005
TX	DENTON AND TARRANT	TX4390481.00	NORTEX MINERALS LP	9/1/2005
TX	DENTON AND TARRANT	TX4390499.01	ANNE CARTWRIGHT FAMILY TR	3/18/2003	DENTON	2008-65818
TX	DENTON AND TARRANT	TX4390499.01	ANNE CARTWRIGHT FAMILY TR		TARRANT	D203127485
TX	DENTON AND TARRANT	TX4390499.02	VICTORIA NEWTON TR	3/15/2003	DENTON	2008-65819
TX	DENTON AND TARRANT	TX4390499.02	VICTORIA NEWTON TR	3/15/2003	TARRANT	D203325911
TX	DENTON AND TARRANT	TX4390499.03	ELIZABETH P CARVER ESTATE	3/15/2003	DENTON	2008-65820
TX	DENTON AND TARRANT	TX4390499.03	ELIZABETH P CARVER ESTATE	3/15/2003	TARRANT	D203325910
TX	DENTON AND TARRANT	TX4390499.04	JEROME CARTWRIGHT IND	3/18/2003	DENTON	2008-65821
TX	DENTON AND TARRANT	TX4390499.04	JEROME CARTWRIGHT IND	3/18/2003	TARRANT	D203127484
TX	DENTON AND TARRANT	TX4390499.05	JEAN CARTWRIGHT DICKSON	3/18/2003	DENTON	2008-65822
TX	DENTON AND TARRANT	TX4390499.05	JEAN CARTWRIGHT DICKSON	3/18/2003	TARRANT	D203127483

Exhibit A, Page 24

3230471v2

PORTIONS OF THIS EXHIBIT DENOTED WITH THREE ASTERISKS (***) HAVE BEEN OMITTED PURSUANT TO A REQUEST FOR CONFIDENTIAL TREATMENT

ST	County	File ID	Lessor	Lease Dated	Recorded County	Vol/Book	Page	Instrument No.
TX	TARRANT AND DENTON	TX1210031.38	SUE A WORKS	5/16/2014	DENTON			2014-61290
TX	TARRANT AND DENTON	TX1210031.38	SUE A WORKS	5/16/2014	TARRANT			D214132772
TX	TARRANT AND DENTON	TX1210005.00	NORTEX MINERALS LP	5/1/2003	DENTON			2004-124550
TX	TARRANT AND DENTON	TX1210005.00	NORTEX MINERALS LP		TARRANT			D203315430
TX	TARRANT AND DENTON	TX1210005.00	NORTEX MINERALS LP	5/1/2003
TX	TARRANT AND DENTON	TX1210005.00	NORTEX MINERALS LP
TX	TARRANT AND DENTON	TX1210005.00	NORTEX MINERALS LP
TX	TARRANT AND DENTON	TX1210005.00	NORTEX MINERALS LP	5/1/2003
TX	TARRANT AND DENTON	TX1210005.00	NORTEX MINERALS LP
TX	TARRANT AND DENTON	TX1210011.01	WAUNITA L CLARK	8/12/2001	DENTON	4931	1803	101800
TX	TARRANT AND DENTON	TX1210011.01	WAUNITA L CLARK	8/12/2001	TARRANT			D203174562
TX	TARRANT AND DENTON	TX1210011.01	WAUNITA L CLARK	8/12/2001
TX	TARRANT AND DENTON	TX1210011.01	WAUNITA L CLARK	8/12/2001
TX	TARRANT AND DENTON	TX1210011.01	WAUNITA L CLARK	8/12/2001
	TARRANT AND DENTON	TX1210011.01	WAUNITA L CLARK	8/12/2001
TX	TARRANT AND DENTON	TX1210011.02	LAURA BETH BRINKER	8/12/2001	DENTON	4931	1807	101801
TX	TARRANT AND DENTON	TX1210011.02	LAURA BETH BRINKER	8/12/2001	TARRANT			D203174564
TX	TARRANT AND DENTON	TX1210011.02	LAURA BETH BRINKER	8/12/2001
TX	TARRANT AND DENTON	TX1210011.02	LAURA BETH BRINKER	8/12/2001
TX	TARRANT AND DENTON	TX1210011.02	LAURA BETH BRINKER	8/12/2001

TX	TARRANT AND DENTON	TX1210011.02	LAURA BETH BRINKER	8/12/2001
TX	TARRANT AND DENTON	TX1210011.03	JACK CROWLEY ET AL	8/27/2001	DENTON	4931	1812	101802
TX	TARRANT AND DENTON	TX1210011.03	JACK CROWLEY ET AL	8/27/2001	TARRANT			D203174561
TX	TARRANT AND DENTON	TX1210011.03	JACK CROWLEY ET AL	8/27/2001
TX	TARRANT AND DENTON	TX1210011.03	JACK CROWLEY ET AL	8/27/2001
TX	TARRANT AND DENTON	TX1210011.03	JACK CROWLEY ET AL	8/27/2001
TX	TARRANT AND DENTON	TX1210011.03	JACK CROWLEY ET AL	8/27/2001
TX	TARRANT AND DENTON	TX1210011.03	JACK CROWLEY ET AL	8/27/2001
TX	TARRANT AND DENTON	TX1210011.03	JACK CROWLEY ET AL	8/27/2001
TX	TARRANT AND DENTON	TX1210012.01	DR WELLS O STEPHENS EST	12/17/2001	DENTON	5000	1164	4043
TX	TARRANT AND DENTON	TX1210012.01	DR WELLS O STEPHENS EST	12/17/2001	TARRANT			D202037586
TX	TARRANT AND DENTON	TX1210012.02	DR C B KENDALL EST	12/17/2001	DENTON	5000	1169	4044
TX	TARRANT AND DENTON	TX1210012.02	DR C B KENDALL EST	12/17/2001	TARRANT			D202037587
TX	TARRANT AND DENTON	TX1210026.01	PBBM NORTHLAKE LTD	3/2/2009	DENTON			2009-60422
TX	TARRANT AND DENTON	TX1210026.01	PBBM NORTHLAKE LTD	3/2/2009
TX	TARRANT AND DENTON	TX1210026.01	PBBM NORTHLAKE LTD	3/2/2009
TX	TARRANT AND DENTON	TX1210026.01	PBBM NORTHLAKE LTD	3/2/2009
TX	TARRANT AND DENTON	TX1210031.13	LUMINANT MINERAL DEVELOPMENT	3/2/2010	DENTON			2010-22559
TX	TARRANT AND DENTON	TX1210031.13	LUMINANT MINERAL DEVELOPMENT	3/2/2010	TARRANT			D210047137
TX	TARRANT AND DENTON	TX1210031.14	JOHN PORTER FARMS INC	4/21/2014	DENTON			2014-41356
TX	TARRANT AND DENTON	TX1210031.14	JOHN PORTER FARMS INC	4/21/2014	TARRANT			D214084785

TX	TARRANT AND DENTON	TX1210031.15	BOB CATES ET UX	4/23/2014	DENTON	2014-41354
TX	TARRANT AND DENTON	TX1210031.15	BOB CATES ET UX	4/23/2014	TARRANT	D214084785
TX	TARRANT AND DENTON	TX1210031.16	JOE CATES ET UX	4/23/2014	DENTON	2014-41355
TX	TARRANT AND DENTON	TX1210031.20	PAUL D COPENHAVER JR ET UX	5/12/2014	DENTON	2014-49254
TX	TARRANT AND DENTON	TX1210031.27	JOHN MURLEY	7/24/2014	DENTON	2014-82676
TX	TARRANT AND DENTON	TX1210031.27	JOHN MURLEY	7/24/2014	TARRANT	D215142691
TX	TARRANT AND DENTON	TX1210031.28	SUE WORKS	5/16/2014	DENTON	2014-61290
TX	TARRANT AND DENTON	TX1210031.28	SUE WORKS	5/16/2014	TARRANT	D214132772
TX	TARRANT AND DENTON	TX1210031.30	PAUL A PINSON ET UX	8/13/2014	TARRANT	D214195144
TX	TARRANT AND DENTON	TX1210031.31	DEBORAH L FLORES	8/13/2014	TARRANT	D214195145
TX	TARRANT AND DENTON	TX1210031.32	WILLIAM A KIRK	8/18/2014	DENTON	2014-100907
TX	TARRANT AND DENTON	TX1210031.32	WILLIAM A KIRK	8/18/2014	TARRANT	D214195142
TX	TARRANT AND DENTON	TX1210031.36	RICHARD N BROWN ET UX	6/26/2014	DENTON	2014-109197
TX	TARRANT AND DENTON	TX1210031.36	RICHARD N BROWN ET UX	6/26/2014	TARRANT	D214225480
TX	TARRANT AND DENTON	TX1210031.37	PAUL DON CRUSE ET UX	10/8/2014	DENTON	2014-109196
TX	TARRANT AND DENTON	TX1210031.37	PAUL DON CRUSE ET UX		TARRANT	D214225481
TX	TARRANT AND DENTON	TX1210031.39	KENNETH MILLER	10/16/2014	DENTON	2014-122345
TX	TARRANT AND DENTON	TX1210031.39	KENNETH MILLER	10/16/2014	TARRANT	D214256085
TX	TARRANT AND DENTON	TX1210031.41	LARRY CARSON TIDWELL ET UX	11/6/2014	DENTON	2015-1219
TX	TARRANT AND DENTON	TX1210031.41	LARRY CARSON TIDWELL ET UX	11/6/2014	TARRANT	D214275922
TX	TARRANT AND DENTON	TX1210031.46	RAYA NEVEEN REDDY ET UX	12/10/2014	DENTON	2015-1217

TX	TARRANT AND DENTON	TX1210031.46	RAYA NEVEEN REDDY ET UX	12/10/2014	TARRANT	D214275920
TX	TARRANT AND DENTON	TX1210031.53	SHERRY BUGG	10/24/2014	DENTON	2015-8217
TX	TARRANT AND DENTON	TX1210031.53	SHERRY BUGG	10/24/2014	TARRANT	D215013067
TX	TARRANT AND DENTON	TX1210031.56	JAMES R HAIRE ET UX	12/18/2014	DENTON	2015-14690
TX	TARRANT AND DENTON	TX1210031.56	JAMES R HAIRE ET UX		TARRANT	D215026331
TX	TARRANT AND DENTON	TX1210031.57	DALE GLEN & STELLA MARIE EDELMAN	1/21/2015	DENTON	2015-14688
TX	TARRANT AND DENTON	TX1210031.57	DALE GLEN & STELLA MARIE EDELMAN	1/21/2015	TARRANT	D215046447
TX	TARRANT AND DENTON	TX1210031.59	KEVIN SIMMONS	2/5/2015	DENTON	2015-26717
	TARRANT AND DENTON	TX1210031.59	KEVIN SIMMONS		TARRANT	D215046448
TX	TARRANT AND DENTON	TX1210031.60	ANGELA DAONNE RAWIE	8/19/2014	DENTON	2015-26718
	TARRANT AND DENTON	TX1210031.60	ANGELA DAONNE RAWIE		TARRANT	D215052665
TX	TARRANT	TX1210031.54	SUSAN BURKE	1/8/2015	TARRANT	D215021177
TX	TARRANT	TX1210031.65	RICK M WATSON ET UX	1/5/2015	TARRANT	D215118278
TX	TARRANT	TX4390439.00	PERRY N BRANUM ET UX	7/4/2005	TARRANT	D205385729
TX	TARRANT	TX4390439.00	PERRY N BRANUM ET UX	7/4/2005
TX	TARRANT	TX4390440.00	RICKY L SONNEVELT	7/5/2005	TARRANT	D205385532
TX	TARRANT	TX4390441.00	SANDRA G SMITH	7/4/2005	TARRANT	D205385531
TX	TARRANT	TX4390442.00	JOYCE L PLUMMER	7/4/2005	TARRANT	D205385527
TX	TARRANT	TX4390443.00	MARJORIE FAY WATT	7/4/2005	TARRANT	D205385541
TX	TARRANT	TX4390444.00	BENNEY MARTIN	7/4/2005	TARRANT	D205385542
TX	TARRANT	TX4390446.00	ROBERT L JOHNSON	3/27/2006	TARRANT	D206194134
TX	TARRANT	TX4390447.00	ANTONIO GARCIA ET UX	3/27/2006	TARRANT	D206194133
TX	TARRANT	TX4390448.00	GLADYS S HAYS TRUSTEE ETAL	3/27/2006	TARRANT	D206194131
TX	TARRANT	TX4390449.00	SUNTRUST EQUITY FUNDING LL	1/17/2006	TARRANT	D206085659
TX	TARRANT	TX4390450.00	TANYA L LAIRD	8/29/2005	TARRANT	D205385539
TX	TARRANT	TX4390451.00	GLADYS HAYS	7/5/2005	TARRANT	D205385736
TX	TARRANT	TX4390452.00	JIMMY EARL MCMILLIN	7/14/2005	TARRANT	D205385544
TX	TARRANT	TX4390452.00	JIMMY EARL MCMILLIN	7/14/2005

TX	TARRANT	TX4390453.00	SUSAN E EASTHAM ET VIR	7/4/2005	TARRANT	D205385732
TX	TARRANT	TX4390455.00	PAUL POLIZZO ET AL	7/4/2005	TARRANT	D205385528
TX	TARRANT	TX4390456.00	REX V BAGBY	3/27/2006	TARRANT	D206194128
TX	TARRANT	TX4390456.00	REX V BAGBY	3/27/2006
TX	TARRANT	TX4390457.00	BONNIE M PALMER	7/4/2005	TARRANT	D205385525
TX	TARRANT	TX4390458.00	STEVEN A FUSCO	7/4/2005	TARRANT	D205358012
TX	TARRANT	TX4390459.00	FIRST BAPTIST CHURCH HASLE	8/18/2005	TARRANT	D205385734
TX	TARRANT	TX4390460.00	WILLIAM E FRISBIE	7/4/2005	TARRANT	D205385735
TX	TARRANT	TX4390460.00	WILLIAM E FRISBIE	7/4/2005
TX	TARRANT	TX4390461.00	CHARLES T JACKSON	7/4/2005	TARRANT	D205385535
TX	TARRANT	TX4390462.00	ALICE M LAIRD ESTATE	7/4/2005	TARRANT	D205385537
TX	TARRANT	TX4390463.00	CINDY J LAIRD	8/11/2005	TARRANT	D205385538
TX	TARRANT	TX4390464.00	MAUDIE C PIKE	7/4/2005	TARRANT	D205385526
TX	TARRANT	TX4390466.00	EULALIA G WALSH	7/4/2005	TARRANT	D205385521
TX	TARRANT	TX4390469.00	MARY ANN CLAUNCH	7/4/2005	TARRANT	D205385730
TX	TARRANT	TX4390469.00	MARY ANN CLAUNCH	7/4/2005
TX	TARRANT	TX4390471.00	NORTEX MINERALS LP	1/1/2006	TARRANT	D206083608
TX	TARRANT	TX4390471.00	NORTEX MINERALS LP	1/1/2006
TX	TARRANT	TX4390471.00	NORTEX MINERALS LP	1/1/2006
TX	TARRANT	TX4390472.00	NORTEX MINERALS LP	3/1/2006	TARRANT	D206157277
TX	TARRANT	TX4390472.00	NORTEX MINERALS LP	3/1/2006
TX	TARRANT	TX4390472.00	NORTEX MINERALS LP	3/1/2006
TX	TARRANT	TX4390472.00	NORTEX MINERALS LP	3/1/2006
TX	TARRANT	TX4390473.00	LUTHER J LEE	3/27/2006	TARRANT	D206194129
TX	TARRANT	TX4390474.00	NORTEX MINERALS LP	7/1/2006	TARRANT	D206264635
TX	TARRANT	TX4390474.00	NORTEX MINERALS LP	7/1/2006
TX	TARRANT	TX4390474.00	NORTEX MINERALS LP	7/1/2006
TX	TARRANT	TX4390475.00	JOEL BULLARD ET AL	7/4/2005	TARRANT	D205296490
TX	TARRANT	TX4390476.00	MARVIN C HICKS ET UX	7/4/2005	TARRANT	D205275273
TX	TARRANT	TX4390478.00	JOLENE J OWEN	7/4/2005	TARRANT	D205296491
TX	TARRANT	TX4390479.00	SABRINA CUSTOM HOMES INC	7/4/2005	TARRANT	D205278478
TX	TARRANT	TX4390480.00	STEPHEN V SALADINO ET UX	7/4/2005	TARRANT	D205278476
TX	TARRANT AND DENTON	TX4390481.00	NORTEX MINERALS LP	9/1/2005	DENTON	2008-51627
TX	TARRANT AND DENTON	TX4390481.00	NORTEX MINERALS LP	9/1/2005	TARRANT	D206181584

TX	TARRANT AND DENTON	TX4390481.00	NORTEX MINERALS LP	9/1/2005
TX	TARRANT AND DENTON	TX4390481.00	NORTEX MINERALS LP	9/1/2005
TX	TARRANT AND DENTON	TX4390481.00	NORTEX MINERALS LP	9/1/2005
TX	TARRANT AND DENTON	TX4390481.00	NORTEX MINERALS LP	9/1/2005
TX	TARRANT	TX4390482.00	JERRY REYNOLDS ET UX	9/27/2004	TARRANT	D204342258
TX	TARRANT	TX4390483.00	FRANCES BALTZELLE ET AL	12/14/2004	TARRANT	D205006114
TX	TARRANT	TX4390484.00	CITY OF FORT WORTH	7/5/2005	TARRANT	D205228842
TX	TARRANT	TX4390488.00	NORTEX MINERALS LP	8/25/2004	TARRANT	D204331034
TX	TARRANT	TX4390488.00	NORTEX MINERALS LP	8/25/2004
TX	TARRANT	TX4390488.00	NORTEX MINERALS LP	8/25/2004	LEASE IS ONLY TARRANT COUNTY
TX	TARRANT	TX4390490.00	DUNCAN TRUST, GEORGIA REEV	7/19/2004	TARRANT	D204251927
TX	TARRANT	TX4390492.00	NORTEX MINERALS LP	8/1/2005	TARRANT	D206079752
TX	TARRANT	TX4390492.00	NORTEX MINERALS LP	8/1/2005
TX	TARRANT	TX4390492.00	NORTEX MINERALS LP	8/1/2005	LEASE IS ONLY TARRANT COUNTY
TX	TARRANT	TX4390493.00	DEWEY EUGENE COZART ET AL	1/31/2003	TARRANT	D203086385
TX	TARRANT	TX4390493.00	DEWEY EUGENE COZART ET AL	1/31/2003
TX	TARRANT	TX4390494.01	RANDALL L KUYKENDALL	4/13/2007	TARRANT	D207160623
TX	TARRANT	TX4390496.00	JOAN MCKINLEY	5/21/2007	TARRANT	D207298724
TX	TARRANT	TX4390497.00	MATTHIAS T SNOW ET UX	5/1/2007	TARRANT	D207239253
TX	TARRANT	TX4390498.00	CITY OF HASLET TEXAS	7/28/2006	TARRANT	D207117708
TX	TARRANT AND DENTON	TX4390499.01	ANNE CARTWRIGHT FAMILY TR	3/18/2003	DENTON	2008-65818
TX	TARRANT AND DENTON	TX4390499.01	ANNE CARTWRIGHT FAMILY TR		TARRANT	D203127485
TX	TARRANT AND DENTON	TX4390499.02	VICTORIA NEWTON TR	3/15/2003	DENTON	2008-65819
TX	TARRANT AND DENTON	TX4390499.02	VICTORIA NEWTON TR	3/15/2003	TARRANT	D203325911
TX	TARRANT AND DENTON	TX4390499.03	ELIZABETH P CARVER ESTATE	3/15/2003	DENTON	2008-65820
TX	TARRANT AND DENTON	TX4390499.03	ELIZABETH P CARVER ESTATE	3/15/2003	TARRANT	D203325910
TX	TARRANT AND DENTON	TX4390499.04	JEROME CARTWRIGHT IND	3/18/2003	DENTON	2008-65821

TX	TARRANT AND DENTON	TX4390499.04	JEROME CARTWRIGHT IND	3/18/2003	TARRANT	D203127484
TX	TARRANT AND DENTON	TX4390499.05	JEAN CARTWRIGHT DICKSON	3/18/2003	DENTON	2008-65822
TX	TARRANT AND DENTON	TX4390499.05	JEAN CARTWRIGHT DICKSON	3/18/2003	TARRANT	D203127483
TX	TARRANT AND DENTON	TX4390500.00	NORTEX MINERALS LP	5/1/2008	TARRANT	D208187570
TX	TARRANT AND DENTON	TX4390500.00	NORTEX MINERALS LP	5/1/2008
TX	TARRANT AND DENTON	TX4390500.00	NORTEX MINERALS LP	5/1/2008
TX	TARRANT AND DENTON	TX4390501.00	NORTEX MINERALS LP	1/15/2007	TARRANT	D207117705
TX	TARRANT AND DENTON	TX4390501.00	NORTEX MINERALS LP	1/15/2007
TX	TARRANT AND DENTON	TX4390501.00	NORTEX MINERALS LP	1/15/2007
TX	TARRANT AND DENTON	TX4390501.00	NORTEX MINERALS LP	1/15/2007
TX	TARRANT	TX4390502.00	BELL HELICOPTER TEXTRON IN	7/14/2006	TARRANT	D206297170
TX	TARRANT	TX4390503.00	JOHN D WASHBURN	7/4/2005	TARRANT	D205385522
TX	TARRANT	TX4390504.00	FERNANDO MORENO SR	7/4/2005	TARRANT	D205385545
TX	TARRANT	TX4390507.01	RICHARD WHATLEY	1/28/2007	TARRANT	D207145911
TX	TARRANT	TX4390507.02	R W WHATLEY JR	1/28/2007	TARRANT	D207107620
TX	TARRANT	TX4390507.03	CHARLES J WHATLEY	1/28/2007	TARRANT	D207107652
TX	TARRANT	TX4390507.04	LINDA C KILLIAN	1/28/2007	TARRANT	D207107615
TX	TARRANT	TX4390507.05	BABIE RUTH PRICE HILL	1/28/2007	TARRANT	D207107619
TX	TARRANT	TX4390507.06	DOROTHY WHATLEY DANIEL	1/28/2007	TARRANT	D207107618
TX	TARRANT	TX4390507.07	LYNDA WHATLEY FRAZIER	1/28/2007	TARRANT	D207107617
TX	TARRANT	TX4390507.08	JANETT ANN WHATLEY ROSE	1/28/2007	TARRANT	D207107616
TX	TARRANT	TX4390507.09	STEPHEN L PRICE JR	1/28/2007	TARRANT	D207107621
TX	TARRANT	TX4390507.10	SUSAN LORAINE DE MELIK	1/28/2007	TARRANT	D207128283
TX	TARRANT	TX4390507.11	FRANCES WHATLEY SHELL	1/28/2007	TARRANT	D207107651
TX	TARRANT	TX4390507.12	THOMAS EDMUND WHATLEY	1/28/2007	TARRANT	D207107646
TX	TARRANT	TX4390507.13	WANDA WHATLEY PERRY	1/28/2007	TARRANT	D207107647
TX	TARRANT	TX4390507.14	EDWARD T SUTTON	1/28/2007	TARRANT	D207107648
TX	TARRANT	TX4390507.15	WYLENNE WHATLEY MCCULLERS	1/28/2007	TARRANT	D207107650

TX	TARRANT	TX4390507.16	BOBBY ODELL WHATLEY	1/28/2007	TARRANT	D207107649
TX	TARRANT	TX4390507.17	CLIFTON A WHATLEY JR	1/28/2007	TARRANT	D207145910
TX	TARRANT	TX4390507.18	JUANITA POWELL	3/27/2006	TARRANT	D206194132
TX	TARRANT	TX4390509.01	GREG A LYON	9/10/2007	TARRANT	D207376727
TX	TARRANT	TX4390509.02	BRADLEY G FELDKAMP	9/10/2007	TARRANT	D207376726
TX	TARRANT	TX4390510.01	JOYCE L PLUMMER	3/27/2006	TARRANT	D206194130
TX	TARRANT	TX4390510.02	LOUIS G ULLRICH	3/21/2007	TARRANT	D207160622
TX	TARRANT	TX4390510.03	CHARLES ULLRICH	3/21/2007	TARRANT	D208088240
TX	TARRANT	TX4390510.04	ETHAL LEAN MCWAIN	1/28/2008	TARRANT	D208085146
TX	TARRANT	TX4390511.99	NORTEX MINERALS LP	8/8/2008	TARRANT	D208313583
TX	TARRANT	TX4390564.00	THOMAS K SENNE ET UX	11/15/2007	TARRANT	D208086932
TX	TARRANT	TX4390565.00	CHARLES C COONS ET UX	4/3/2008	TARRANT	D208167620
TX	TARRANT	TX4390566.00	FARRUKH AZIM	4/3/2008	TARRANT	D208157508
TX	TARRANT	TX4390567.00	MARK E DUNN ET UX	11/15/2007	TARRANT	D208086950
TX	TARRANT	TX4390568.00	BYRON S JOBE	11/15/2007	TARRANT	D208086969
TX	TARRANT	TX4390569.00	BRANDON L MILLER ET UX	4/3/2008	TARRANT	D208157530
TX	TARRANT	TX4390570.00	TEDDIE W ROCKWELL ET UX	4/3/2008	TARRANT	D208167621
TX	TARRANT	TX4390571.00	J DREW MICHAEL	4/3/2008	TARRANT	D208157465
TX	TARRANT	TX4390572.00	WILLIAM STEWART ET UX	11/15/2007	TARRANT	D208086900
TX	TARRANT	TX4390573.00	DAVID HANNAH ET UX	11/15/2007	TARRANT	D208086905
TX	TARRANT	TX4390574.00	LINDSAY M HARMON AIF YATES	4/3/2008	TARRANT	D208167624
TX	TARRANT	TX4390575.00	STACEY WHITEHEAD	11/15/2007	TARRANT	D208086959
TX	TARRANT	TX4390576.00	LORETTA A HOLCOMBE	4/3/2008	TARRANT	D208157469
TX	TARRANT	TX4390577.00	SUZANNAH P NIELSEN ET VIR	4/3/2008	TARRANT	D208157478
TX	TARRANT	TX4390578.00	LEROY D SWAMMY ET UX	11/15/2007	TARRANT	D208086948
TX	TARRANT	TX4390579.00	DARREN J COLLINS ET UX	2/7/2008	TARRANT	D208086963
TX	TARRANT	TX4390580.00	DONALD J PITTENGER JR	2/7/2008	TARRANT	D208086955
TX	TARRANT	TX4390581.00	JACQUELINE K RITZ MELMAN	11/15/2007	TARRANT	D208086907
TX	TARRANT	TX4390582.00	RHONDA K WHITINGTON	11/15/2007	TARRANT	D208086917
TX	TARRANT	TX4390583.00	SHANE GULDBRANSEN ET UX	2/7/2008	TARRANT	D208086979
TX	TARRANT	TX4390584.00	LAURA BRICE	4/3/2008	TARRANT	D208157529
TX	TARRANT	TX4390585.00	ALFREDO MADRID	11/15/2007	TARRANT	D208086975
TX	TARRANT	TX4390586.00	CHRISTOPHER D CRAWFORD	4/3/2008	TARRANT	D208157509
TX	TARRANT	TX4390587.00	SPENCER A MCFARLAND ET UX	11/15/2007	TARRANT	D208086890
TX	TARRANT	TX4390588.00	MARCO TORO ET AL	11/15/2007	TARRANT	D208086886

TX	TARRANT	TX4390597.00	CITY OF FORT WORTH	8/1/2008	TARRANT	D208410221
TX	TARRANT	TX4390599.00	JAMIE CARMACK ET UX	11/15/2007	TARRANT	D208086913
TX	TARRANT	TX4390600.00	DAVID ALLEN BACH ET UX	3/30/2008	TARRANT	D208157534
TX	TARRANT	TX4390601.00	SHERRY L GRAY KENNEL KARE	3/15/2008	TARRANT	D208157459
TX	TARRANT	TX4390602.00	CHARLENE STEWART JACKSON I	4/21/2008	TARRANT	D208157533
TX	TARRANT	TX4390603.00	JAMES K GRAHAM ET UX	2/7/2008	TARRANT	D208086974
TX	TARRANT	TX4390604.00	JOHN M HUGGARD ET UX	11/15/2007	TARRANT	D208086973
TX	TARRANT	TX4390605.00	BRIAN L SEEFELDT ET UX	11/15/2007	TARRANT	D208086922
TX	TARRANT	TX4390606.00	BRYAN PHILLIPS ET UX	11/15/2007	TARRANT	D208086952
TX	TARRANT	TX4390607.00	DEREK W PORTER ET UX	11/15/2007	TARRANT	D208086931
TX	TARRANT	TX4390608.00	MARK T BASHAM ET UX	11/15/2007	TARRANT	D208086972
TX	TARRANT	TX4390609.00	AUGUSTIN MANTEZOLO ET UX	11/15/2007	TARRANT	D208086996
TX	TARRANT	TX4390610.00	VICTOR CHACON	11/15/2007	TARRANT	D208086895
TX	TARRANT	TX4390611.00	HOLLY A TEWKSBURY ET VIR	11/15/2007	TARRANT	D208086986
TX	TARRANT	TX4390612.00	DANIEL E RICHARDSON	11/15/2007	TARRANT	D208157457
TX	TARRANT	TX4390613.00	LOST SPURS RANCH APARTMENT	3/15/2008	TARRANT	D208157535
TX	TARRANT	TX4390614.00	ARTHUR LYON JR	11/15/2007	TARRANT	D208086887
TX	TARRANT	TX4390615.00	JOSE FRANCISCO OLGUIN	11/15/2007	TARRANT	D208086945
TX	TARRANT	TX4390616.00	KELLY A STANBERY	11/15/2007	TARRANT	D208086941
TX	TARRANT	TX4390617.00	JUSTIN BERNDT ET UX	4/3/2008	TARRANT	D208157482
TX	TARRANT	TX4390618.00	PAMELA TENNISON	4/3/2008	TARRANT	D208191990
TX	TARRANT	TX4390619.00	FRANK S DURHAM III ET UX	4/3/2008	TARRANT	D208157518
TX	TARRANT	TX4390620.00	CASSANDRA WATKINS	4/3/2008	TARRANT	D208241463
TX	TARRANT	TX4390621.00	JAMES R KARG ET UX	4/10/2008	TARRANT	D208157460
TX	TARRANT	TX4390622.00	CHARLES DAVID MARSH ET UX	4/10/2008	TARRANT	D208157461
TX	TARRANT	TX4390623.00	MARY ANN DAWSON	4/3/2008	TARRANT	D208157477
TX	TARRANT	TX4390625.00	MARK HICKOK & TROY HODGES	11/15/2007	TARRANT	D208086980
TX	TARRANT	TX4390626.00	CHANDLER CROUCH ET UX	4/3/2008	TARRANT	D208157532
TX	TARRANT	TX4390627.00	PABLO XIQUES/ KAREN XIQUES	4/3/2008	TARRANT	D208157499
TX	TARRANT	TX4390628.00	KEVIN MORRIS ET UX	4/3/2008	TARRANT	D208157464
TX	TARRANT	TX4390629.00	RICARDO SALAS ET UX	11/15/2007	TARRANT	D208086984
TX	TARRANT	TX4390630.00	IVAN CHARLES MCBRIDE ET UX	11/15/2007	TARRANT	D208086946
TX	TARRANT	TX4390631.00	STERLING L MULLIGAN ET UX	11/15/2007	TARRANT	D208086953
TX	TARRANT	TX4390632.00	DAVID R PETERSON ET UX	11/15/2007	TARRANT	D208086971
TX	TARRANT	TX4390633.00	ANDREW A BRINSON ET UX	2/7/2008	TARRANT	D208086954

TX	TARRANT	TX4390634.00	RODNEY GEISLER ET UX	11/15/2007	TARRANT	D208086909
TX	TARRANT	TX4390635.00	APUL LUMBANTOBING	11/15/2007	TARRANT	D208086911
TX	TARRANT	TX4390636.00	STEVEN B MOOTY ET UX	11/15/2007	TARRANT	D208157455
TX	TARRANT	TX4390637.00	KEVIN B TROTMAN ET U X	2/7/2008	TARRANT	D208086957
TX	TARRANT	TX4390638.00	LOUIS A REED ET UX	4/3/2008	TARRANT	D208157484
TX	TARRANT	TX4390639.00	NICK S BEAM ET UX	4/3/2008	TARRANT	D208157488
TX	TARRANT	TX4390640.00	JASON W CHRISTIAN ET UX	4/3/2008	TARRANT	D208157497
TX	TARRANT	TX4390641.00	STEPHEN E ANDERSON ET UX	4/3/2008	TARRANT	D208157491
TX	TARRANT	TX4390642.00	MARKUS L MURRAY ET UX	4/3/2008	TARRANT	D208157494
TX	TARRANT	TX4390643.00	HOWARD ROUTON ET UX	11/15/2007	TARRANT	D208086908
TX	TARRANT	TX4390644.00	DEREK BAKER ET UX	11/15/2007	TARRANT	D208086935
TX	TARRANT	TX4390646.00	TIMOTHY A COBB	11/15/2007	TARRANT	D208086940
TX	TARRANT	TX4390647.00	LARRY CERVANTES ET UX	4/3/2008	TARRANT	D208157507
TX	TARRANT	TX4390648.00	JAMES B IRWIN	2/7/2008	TARRANT	D208086960
TX	TARRANT	TX4390649.00	MARCOS NEVAREZ ET UX	2/7/2008	TARRANT	D208086958
TX	TARRANT	TX4390651.00	JON E RUTLEDGE ET UX	11/15/2007	TARRANT	D208086919
TX	TARRANT	TX4390652.00	JODY R HUCKABY	11/15/2007	TARRANT	D208086933
TX	TARRANT	TX4390653.00	MICHELE PIEROTTI	11/15/2007	TARRANT	D208086899
TX	TARRANT	TX4390654.00	PENNI L BURT	2/7/2008	TARRANT	D208086967
TX	TARRANT	TX4390655.00	SYLVIA RAMOS	11/15/2007	TARRANT	D208086927
TX	TARRANT	TX4390656.00	LILLIE ANN GLOVER ET AL	11/15/2007	TARRANT	D208086982
TX	TARRANT	TX4390658.00	SHANNON TODD FERGUSON	11/15/2007	TARRANT	D208086928
TX	TARRANT	TX4390659.00	RICHARD S BRIGGS ET UX	11/15/2007	TARRANT	D208086989
TX	TARRANT	TX4390660.00	LEVI J MILLER ET UX	11/15/2007	TARRANT	D208086926
TX	TARRANT	TX4390661.00	DEREK SCEARCE ET UX	11/15/2007	TARRANT	D208086898
TX	TARRANT	TX4390662.00	MARTIN RAMOS JR ET UX	11/15/2007	TARRANT	D208086925
TX	TARRANT	TX4390663.00	HOWELL FINNIGAN ET UX	11/15/2007	TARRANT	D208086951
TX	TARRANT	TX4390664.00	BRIAN ALLEN ET UX	11/15/2007	TARRANT	D208086936
TX	TARRANT	TX4390665.00	DAVID THIBODEAUX ET UX	11/15/2007	TARRANT	D208086904
TX	TARRANT	TX4390666.00	KELLI PHILLIPS	4/3/2008	TARRANT	D208157476
TX	TARRANT	TX4390667.00	NANCY E REID	4/3/2008	TARRANT	D208167622
TX	TARRANT	TX4390668.00	REX DILLINGHAM	4/3/2008	TARRANT	D208157467
TX	TARRANT	TX4390669.00	BRETT SCHRITTER ET UX	4/3/2008	TARRANT	D208157480
TX	TARRANT	TX4390670.00	ADAN RAMIREZ ET UX	4/3/2008	TARRANT	D208157474
TX	TARRANT	TX4390671.00	JUAN F REALEGENO ET UX	4/3/2008	TARRANT	D208157470

TX	TARRANT	TX4390672.00	JAMES M FEARS IV ET UX	4/3/2008	TARRANT	D208157479
TX	TARRANT	TX4390673.00	JOSE ANTONIO CINTRON ET UX	4/3/2008	TARRANT	D208157505
TX	TARRANT	TX4390674.00	IVAN WINROTH AIF DIEGO D	4/3/2008	TARRANT	D208167623
TX	TARRANT	TX4390675.00	JEREMY W FINCH ET UX	4/3/2008	TARRANT	D208157466
TX	TARRANT	TX4390676.00	DEBRA FITTS	11/15/2007	TARRANT	D208086889
TX	TARRANT	TX4390678.00	DOROTHY COSAND	4/3/2008	TARRANT	D208157492
TX	TARRANT	TX4390679.00	SABRA L DAGEL LAMAR	4/3/2008	TARRANT	D208157490
TX	TARRANT	TX4390680.00	MATTHEW S HOFFMAN	4/3/2008	TARRANT	D208157495
TX	TARRANT	TX4390681.00	FELIX MORALES ET UX	4/3/2008	TARRANT	D208157493
TX	TARRANT	TX4390682.00	JENNIFER DAVIS BYRD	4/3/2008	TARRANT	D208157496
TX	TARRANT	TX4390683.00	TIMOTHY S ASHWORTH	4/3/2008	TARRANT	D208157525
TX	TARRANT	TX4390684.00	CHRISTOPHER G STEVENS	4/3/2008	TARRANT	D208157517
TX	TARRANT	TX4390685.00	JOHN SCOTT JOHNSON ET UX	4/3/2008	TARRANT	D208157521
TX	TARRANT	TX4390686.00	DAVID A MARTIN ET UX	4/3/2008	TARRANT	D208157487
TX	TARRANT	TX4390687.00	PAUL A ROBINSON ET UX	4/3/2008	TARRANT	D208157527
TX	TARRANT	TX4390688.00	CHRISTOPHER W RAPPLEYE ET	4/3/2008	TARRANT	D208157524
TX	TARRANT	TX4390689.00	TAD LELAND RIZER ET UX	4/3/2008	TARRANT	D208157510
TX	TARRANT	TX4390690.00	JAMES GREGORY FONTENOT	11/15/2007	TARRANT	D208086893
TX	TARRANT	TX4390691.00	HEATHER M CROSETTI	11/15/2007	TARRANT	D208086944
TX	TARRANT	TX4390692.00	SHANNON R PRESLEY	11/15/2007	TARRANT	D208086888
TX	TARRANT	TX4390693.00	BRENDA L NEAGLE	11/15/2007	TARRANT	D208086992
TX	TARRANT	TX4390694.00	DAVID HEBENSTREIT	11/15/2007	TARRANT	D208086910
TX	TARRANT	TX4390695.00	RASEC BARRIENTOS	11/15/2007	TARRANT	D208157458
TX	TARRANT	TX4390696.00	ATHENA L LOGAN	11/15/2007	TARRANT	D208086902
TX	TARRANT	TX4390697.00	H A MILLS ET UX	11/15/2007	TARRANT	D208086914
TX	TARRANT	TX4390698.00	LIZANDRO NARANJO ET UX	11/15/2007	TARRANT	D208086906
TX	TARRANT	TX4390699.00	CHRISTOPHER WILLIAMSON ET	11/15/2007	TARRANT	D208086885
TX	TARRANT	TX4390700.00	RUDY B ENCINAS ET UX	11/15/2007	TARRANT	D208086939
TX	TARRANT	TX4390701.00	PATRICK SCOTT CASTINE ET U	11/15/2007	TARRANT	D208086947
TX	TARRANT	TX4390702.00	JEFFREY A VOGEL ET UX	11/15/2007	TARRANT	D208086942
TX	TARRANT	TX4390703.00	SUNNY YOUNG ET AL	11/15/2007	TARRANT	D208086891
TX	TARRANT	TX4390704.00	DENISE R KENNEDY	2/7/2008	TARRANT	D208086962
TX	TARRANT	TX4390705.00	MICHAEL A BRANDENBURGH ET	11/15/2007	TARRANT	D208086924
TX	TARRANT	TX4390706.00	LESLIE R NICAISE JR	11/15/2007	TARRANT	D208086901
TX	TARRANT	TX4390707.00	REBECCA F BURTON	11/15/2007	TARRANT	D208086985

TX	TARRANT	TX4390708.00	MICHELE R STYKEL	2/7/2008	TARRANT	D208086956
TX	TARRANT	TX4390709.00	JEFFREY GODWIN ET AL	2/7/2008	TARRANT	D208086964
TX	TARRANT	TX4390710.00	JAMES D LOVE ET UX	11/15/2007	TARRANT	D208086929
TX	TARRANT	TX4390711.00	MARC SANTINI ET UX	2/7/2008	TARRANT	D208157456
TX	TARRANT	TX4390712.00	MARK A PIERCE ET UX	2/7/2008	TARRANT	D208086961
TX	TARRANT	TX4390713.00	DANIEL T ROBISON ET UX	11/15/2007	TARRANT	D208086970
TX	TARRANT	TX4390714.00	JOHN R GOOLSBY ET UX	2/7/2008	TARRANT	D208086977
TX	TARRANT	TX4390716.00	RACHAEL D ROURE	4/3/2008	TARRANT	D208157485
TX	TARRANT	TX4390718.00	SYED ATHER IMAM	4/3/2008	TARRANT	D208157514
TX	TARRANT	TX4390719.00	OMAR RODRIGUEZ	4/3/2008	TARRANT	D208157501
TX	TARRANT	TX4390720.00	FRANSISCO A COVARRUBIAS	4/3/2008	TARRANT	D208157526
TX	TARRANT	TX4390721.00	GABRIEL GUZMAN	4/3/2008	TARRANT	D208157486
TX	TARRANT	TX4390722.00	ERIC D WATERS	4/3/2008	TARRANT	D208157463
TX	TARRANT	TX4390723.00	DANIEL YUBETA JR ET UX	4/3/2008	TARRANT	D208157489
TX	TARRANT	TX4390724.00	RASHID J RAHAMAN ET UX	4/3/2008	TARRANT	D208157504
TX	TARRANT	TX4390725.00	RON S PETTY ET UX	4/3/2008	TARRANT	D208157473
TX	TARRANT	TX4390726.00	DAVID PAUL PALMER ET UX	4/3/2008	TARRANT	D208157531
TX	TARRANT	TX4390727.00	ALAN KOLMEIER ET UX	4/3/2008	TARRANT	D208157498
TX	TARRANT	TX4390734.00	B H LUSCOMBE & K A COVERLY	11/15/2007	TARRANT	D208086921
TX	TARRANT	TX4390735.00	JEFFREY R SMOUT ET UX	4/3/2008	TARRANT	D208157511
TX	TARRANT	TX4390736.00	CECILIA SALIMIAN	11/15/2007	TARRANT	D208086892
TX	TARRANT	TX4390737.00	TED G ELLIS ET UX	11/15/2007	TARRANT	D208086934
TX	TARRANT	TX4390738.00	JEFFERY M MILLER ET UX	11/15/2007	TARRANT	D208086991
TX	TARRANT	TX4390739.00	KEVIN KUDRNA	4/3/2008	TARRANT	D208157528
TX	TARRANT	TX4390740.00	WILLIAM CLARKE	11/15/2007	TARRANT	D208086912
TX	TARRANT	TX4390741.00	DARREN KEITH MILLER ET UX	11/15/2007	TARRANT	D208086990
TX	TARRANT	TX4390742.00	RAMON H GALLO ET UX	11/15/2007	TARRANT	D208086976
TX	TARRANT	TX4390743.00	SHADAWN S BROWN	4/3/2008	TARRANT	D208157513
TX	TARRANT	TX4390744.00	DIMONE MEYA ET UX	4/3/2008	TARRANT	D208157516
TX	TARRANT	TX4390745.00	JAVIER RODRIGUEZ	4/3/2008	TARRANT	D208157462
TX	TARRANT	TX4390746.00	JULIO SOLIS ET UX	2/7/2008	TARRANT	D208086966
TX	TARRANT	TX4390747.00	JACOB D WEST	11/15/2007	TARRANT	D208086923
TX	TARRANT	TX4390748.00	JEROME MORGAN ET UX	11/15/2007	TARRANT	D208086988
TX	TARRANT	TX4390749.00	ERIK A DECAIRE ET UX	11/15/2007	TARRANT	D208086949
TX	TARRANT	TX4390750.00	DEWAYNE WINROW ET UX	4/3/2008	TARRANT	D208157520

TX	TARRANT	TX4390751.00	SHERI H BALLARD	2/7/2008	TARRANT	D208086965
TX	TARRANT	TX4390752.00	DONNY PARSONS	4/3/2008	TARRANT	D208157515
TX	TARRANT	TX4390753.00	SUSAN FIRES ET VIR	4/3/2008	TARRANT	D208157506
TX	TARRANT	TX4390754.00	WILLIAM W CALLAHAN ET UX	4/3/2008	TARRANT	D208157503
TX	TARRANT	TX4390755.00	FIDEL MACIAS ET UX	10/24/2007	TARRANT	D208086978
TX	TARRANT	TX4390756.00	MICHELLE M BRASUELL-FIFE	2/7/2008	TARRANT	D208086968
TX	TARRANT	TX4390757.00	MATTHEW KENNEDY ET UX	11/15/2007	TARRANT	D208086894
TX	TARRANT	TX4390758.00	LAWRENCE ADAMS ET UX	11/15/2007	TARRANT	D208086903
TX	TARRANT	TX4390767.00	JOSE & JORGE MONTOYA	4/3/2008	TARRANT	D208157481
TX	TARRANT	TX4390768.00	NAOMI PEASE ET VIR	11/15/2007	TARRANT	D208086916
TX	TARRANT	TX4390769.00	JAMES A GRICE ET UX	11/15/2007	TARRANT	D208086987
TX	TARRANT	TX4390770.00	LEISHA & CLIFTON SHELTON	4/3/2008	TARRANT	D208157468
TX	TARRANT	TX4390771.00	ROBERT KNOWLTON ET UX	2/7/2008	TARRANT	D208086981
TX	TARRANT	TX4390772.00	SUSAN HORD ACREY ET VIR	7/25/2001	TARRANT	D201249809
TX	TARRANT	TX4390773.00	KENNER REALTY CORPORATION	2/7/2008	TARRANT	D208086994
TX	TARRANT	TX4390774.00	SHERMAN & AMY TRYON	4/3/2008	TARRANT	D208157523
TX	TARRANT	TX4390775.00	THOMAS AND DEBORAH WALSH	11/15/2007	TARRANT	D208086943
TX	TARRANT	TX4390776.00	JEFFREY & CONNIE JOHNSON	11/15/2007	TARRANT	D208086937
TX	TARRANT	TX4390777.00	DANIEL & AMANDA RAWLS	4/3/2008	TARRANT	D208157522
TX	TARRANT	TX4390778.00	RONALD SLONAKER ET UX	4/3/2008	TARRANT	D208157512
TX	TARRANT	TX4390779.00	BRANDY & DAVID GREEN	11/15/2007	TARRANT	D208086915
TX	TARRANT	TX4390780.00	CARLOS CARBALLO	4/3/2008	TARRANT	D208157500
TX	TARRANT	TX4390781.00	JOSHUA & KACIE CROWDER	4/3/2008	TARRANT	D208157519
TX	TARRANT	TX4390782.00	ARLENE & STEVE SARK	11/15/2007	TARRANT	D208086897
TX	TARRANT	TX4390783.00	BRANDON & STACY BEARD	11/15/2007	TARRANT	D208086993
TX	TARRANT	TX4390784.00	JON R CREIGHTON	2/7/2008	TARRANT	D208157454
TX	TARRANT	TX4390786.00	WILLIAM JOSEPH TUCKER ET U	12/4/2008	TARRANT	D208461225
TX	TARRANT	TX4390788.00	K GILL & KENDRA WALKER	11/15/2007	TARRANT	D208086938
TX	TARRANT	TX4390789.00	VINCENT MAGANA ET UX	4/3/2008	TARRANT	D208157483
TX	TARRANT	TX4390790.00	KEVIN L KLOIBER ET UX	4/3/2008	TARRANT	D208157472
TX	TARRANT	TX4390791.00	COREY DON CHAMBERS	4/3/2008	TARRANT	D208157471
TX	TARRANT	TX4390793.00	EMMA M BREWER TURPEN ET AL	3/7/2003	TARRANT	D203145423
TX	TARRANT	TX4390793.00	EMMA M BREWER TURPEN ET AL	3/7/2003
TX	TARRANT	TX4390793.00	EMMA M BREWER TURPEN ET AL	3/7/2003		D203145423
TX	TARRANT	TX4390793.00	EMMA M BREWER TURPEN ET AL	3/7/2003

TX	TARRANT	TX4390793.00	EMMA M BREWER TURPEN ET AL	3/7/2003
TX	TARRANT	TX4390793.00	EMMA M BREWER TURPEN ET AL	3/7/2003
TX	TARRANT	TX4390793.00	EMMA M BREWER TURPEN ET AL	3/7/2003
TX	TARRANT	TX4390793.00	EMMA M BREWER TURPEN ET AL	3/7/2003
TX	TARRANT	TX4390793.00	EMMA M BREWER TURPEN ET AL	3/7/2003
TX	TARRANT	TX4390817.00	JAMES KENNETH WIGGINS ET U	7/25/2001	TARRANT	D201249811
TX	TARRANT	TX4390825.00	EUGENE PHILIP BURTNER ET A	7/1/2008	TARRANT	D208268485
TX	TARRANT	TX4390826.00	DONALD L HUDGINS JR ET AL	5/10/2008	TARRANT	Duplicate Original D208191991
TX	TARRANT	TX4390826.00	DONALD L HUDGINS JR ET AL	5/10/2008	TARRANT	D208420204
TX	TARRANT	TX4390828.01	PHILLIP K SOTEL 2000 TRUST	8/5/2002	TARRANT	D202326159
TX	TARRANT	TX4390828.02	FRANCES L CLARK	8/5/2002	TARRANT	D203023488
TX	TARRANT	TX4390847.00	FREDERIK FLOREN TRUSTEE	3/3/2003	TARRANT	D203103742
TX	TARRANT	TX4390847.00	FREDERIK FLOREN TRUSTEE	3/3/2003
TX	TARRANT	TX4390848.00	DAVID TOM MCPHERSON ET UX	4/28/2008	TARRANT	D208191989
TX	TARRANT	TX4390850.00	KENNETH W BRADLEY ET UX	5/8/2008	TARRANT	D208191988
TX	TARRANT	TX4390852.00	WILLIAM & INA B JAMESON REV TR	10/24/2002	TARRANT	D203145442
TX	TARRANT	TX4390852.00	WILLIAM & INA B JAMESON REV TR	10/24/2002
TX	TARRANT	TX4390852.00	WILLIAM & INA B JAMESON REV TR	10/24/2002
TX	TARRANT	TX4390877.00	ALLIANCE HOTEL II LTD	3/17/2009	TARRANT	D209128427
TX	TARRANT	TX4390878.00	SAGAMORE-FORT WORTH LP	3/17/2009	TARRANT	D209128428
TX	TARRANT	TX4390916.99	ALICE LAVON BREWER	6/29/2009	TARRANT	D209177830
TX	TARRANT	TX4390920.99	SUSAN ACREY	8/31/2009	TARRANT	D209235059
TX	TARRANT AND DENTON	TX4390921.00	MOUNT OLIVET CEMETERY ASSN	8/3/2009	TARRANT	D209208077
TX	TARRANT AND DENTON	TX4390921.00	MOUNT OLIVET CEMETERY ASSN	8/3/2009	DENTON	2009-95113
TX	TARRANT	TX4390923.00	ST TX MF-110200	7/14/2009	TARRANT	D209202877
TX	TARRANT	TX4390958.99	STEVEN W NORTHINGTON	11/10/2009	TARRANT	D209303332
TX	TARRANT	TX4390960.00	TODD FAMILY LIVING TRUST	12/2/2009	TARRANT	D209323848
TX	TARRANT	TX4390961.00	PAUL WILBANKS ET UX	12/2/2009	TARRANT	D209323847
TX	TARRANT	TX4390964.00	JOHN C MCGAUGH	12/14/2009	TARRANT	D210016299
TX	TARRANT	TX4390965.00	KEVIN A LEE ET UX	12/14/2009	TARRANT	D210016300

TX	TARRANT	TX4390966.00	MARIELLA E UGAZ ET VIR	12/14/2009	TARRANT			D210016301
TX	TARRANT	TX4390971.00	CHAD A WHITE ET UX	12/7/2009	TARRANT			D210016302
TX	TARRANT	TX4390978.00	ST TX 110640	3/23/2010	TARRANT			D210092561
TX	TARRANT	TX4390983.01	PCP LOST CREEK RANCH NORTH	2/1/2010	TARRANT			D210107250
TX	TARRANT	TX4390983.02	D L HUDGINS JR	2/1/2010	TARRANT			D210107249
TX	TARRANT	TX4390984.00	SCOTT GRAZER ET UX	2/12/2010	TARRANT			D210042820
TX	TARRANT	TX4390987.00	ODETTE NGOIE TSHISEKEDI ET AL	2/12/2010	TARRANT			D210042817
TX	TARRANT	TX4390988.00	LOST SPURS DEVELOPMENT INC	2/1/2010	TARRANT			D210107248
TX	TARRANT	TX4390999.00	VIRGINIA ARMENDARIZ	3/24/2010	TARRANT			D210092557
TX	TARRANT	TX4391000.00	JAIMARIE SANTOS-ROMAN ET VIR	3/15/2010	TARRANT			D210092558
TX	TARRANT	TX4391001.00	TARE L DURR ET VIR	3/24/2010	TARRANT			D210092559
TX	TARRANT	TX4391007.00	RICHARD BARBER ET UX	3/25/2010	TARRANT			D210078911
TX	TARRANT	TX4391011.00	MICHAEL K THURMAN ET UX	4/15/2010	TARRANT			D210092560
TX	TARRANT	TX4391013.00	JEAN PHILLIPE ISSOM ET UX	4/23/2010	TARRANT			D210107278
TX	TARRANT	TX4391014.00	AMIR HONARDAR	4/26/2010	TARRANT			D210123322
TX	TARRANT	TX4391016.00	NICOLE OLBRICH MEEK ET VIR	5/4/2010	TARRANT			D210107277
TX	TARRANT	TX4391019.00	TONY COUGHLIN ET UX	4/12/2010	TARRANT			D210123323
TX	TARRANT	TX4391025.01	LONZO E MEDLIN TRUST	8/29/2001	TARRANT			D201211727
TX	TARRANT	TX4391025.01	LONZO E MEDLIN TRUST	8/29/2001
TX	TARRANT	TX4391025.02	FLEISCHAKER MINERAL CO	1/16/2001	TARRANT			D201277370
TX	TARRANT	TX4391025.02	FLEISCHAKER MINERAL CO	1/16/2001
TX	TARRANT	TX4391025.03	FLEISCHAKER MINERAL CO LLC	1/15/2010	TARRANT			D210042824
TX	TARRANT	TX4391025.04	LANGSTON MINERAL ET AL	4/1/2010	TARRANT			D210155884
TX	TARRANT	TX4391026.01	MARGARET R SCHLUTER	9/13/2001	TARRANT	15268	73	D201284943
TX	TARRANT	TX4391026.01	MARGARET R SCHLUTER	9/13/2001
TX	TARRANT	TX4391026.02	REYNOLDS CHAR TRUST	11/15/2001	TARRANT	15281	430	D201291010
TX	TARRANT	TX4391026.02	REYNOLDS CHAR TRUST	11/15/2001
TX	TARRANT	TX4391026.03	N LILLIAN & S REYNOLDS CHAR TR	4/1/2010	TARRANT			D210199520
TX	TARRANT	TX4391026.04	MARGARET R HUGHES	4/1/2010	TARRANT			D210155885
TX	TARRANT	TX4391027.00	VIVIANE L SCHMUTZLER ET VIR	6/9/2010	TARRANT			D210139574
TX	TARRANT	TX4391028.00	BRANTON K LOEWEN ET UX	5/18/2010	TARRANT			D210139575
TX	TARRANT	TX4391038.00	B-TEX MINERALS LP	8/9/2010	TARRANT			D210193026
TX	TARRANT	TX4391041.00	NORTEX MINERALS LP	8/4/2010	TARRANT			D210217434
TX	TARRANT	TX4391043.00	AMBER A BOS	7/28/2010	TARRANT			D210201300

TX	TARRANT	TX4391045.00	DARREN W JOHNSTON	6/23/2010	TARRANT			D210211172
TX	TARRANT	TX4391046.00	KELLY WEBBER	8/6/2010	TARRANT			D210201298
TX	TARRANT	TX4391047.00	MITCHELL TODD	8/16/2010	TARRANT			D210211173
TX	TARRANT	TX4391048.00	ROBERT KYLE ROGERS ET UX	8/16/2010	TARRANT			D210206464
TX	TARRANT	TX4391049.00	TINA MORALES	8/16/2010	TARRANT			D210201299
TX	TARRANT	TX4391053.00	ZHI WANG & XIAPING QU	8/18/2010	TARRANT			D210206465
TX	TARRANT	TX4391061.00	SHENG-FANG HUANG ET UX	8/31/2010	TARRANT			D210220317
TX	TARRANT	TX4391063.00	ANG ANDREW OUM	8/31/2010	TARRANT			D210220316
TX	TARRANT	TX4391067.00	ERIC W BURISKY	8/16/2010	TARRANT			D210229109
TX	TARRANT	TX4391270.00	THOMAS E RADELL ET UX	4/19/2011	TARRANT			D211099720
TX	TARRANT	TX4391301.00	XIANPING QU & ZHI WANG	9/14/2011	TARRANT			D211226008
TX	TARRANT	TX4391311.00	NORTEX MINERALS LP	10/12/2011	TARRANT			D211253270
TX	TARRANT	TX4391364.01	EAGLE FARMS INC	4/21/2014	TARRANT			D214084784
TX	TARRANT	TX4391365.01	ROY & EMMA FREER INDIV & TREES	5/13/2014	TARRANT			D214132771
TX	TARRANT	TX4391367.00	LOTTIE BARTON JOHNSON	8/12/1985	TARRANT	8306	1547
TX	TARRANT	TX1210031.33	ROGER DALE JORDAN ET UX	9/24/2014	TARRANT			D214216579
TX	TARRANT	TX1210031.42	JIMMY CHARLES MOSLEY ET UX	10/24/2014	TARRANT			D214256084
TX	TARRANT	TX1210031.43	JEFFREY SCOTT CORNELIUS ET UX	11/10/2014	TARRANT			D214256086
TX	TARRANT	TX1210031.44	DONALD R STARNES ET UX	10/21/2014	TARRANT			D214275918
TX	TARRANT	TX1210031.45	TAMELA L GILLHAM	7/30/2014	TARRANT			D214275917
TX	TARRANT	TX1210031.50	GARY D LARIMER ET UX	12/9/2014	TARRANT			D215002808
TX	TARRANT	TX1210031.51	PHILIP R BOYD	10/17/2014	TARRANT			D215008926
TX	TARRANT	TX1210031.61	FRANK ROSNER ET UX	3/3/2015	TARRANT			D215055162
TX	TARRANT	TX1210031.62	PHILLIP WARREN JOHNSON	3/5/2015	TARRANT			D215068008
TX	TARRANT	TX1210031.63	RODNEY A NESBITT ET UX	7/30/2014	TARRANT			D215118279
TX	DENTON AND TARRANT	TX1210001.00	NORTEX MINERALS LP	12/1/2006	DENTON			2007-30172
TX	DENTON AND TARRANT	TX1210001.00	NORTEX MINERALS LP	12/1/2006
TX	DENTON AND TARRANT	TX1210002.00	NORTEX MINERALS LP	12/15/2005	DENTON			2006-35282
TX	DENTON AND TARRANT	TX1210002.00	NORTEX MINERALS LP	12/15/2005
TX	DENTON AND TARRANT	TX1210003.00	NORTEX MINERALS LP	12/31/2005	DENTON			2006-72364

TX	DENTON AND TARRANT	TX1210003.00	NORTEX MINERALS LP	12/31/2005
TX	DENTON AND TARRANT	TX1210004.00	NORTEX MINERALS LP	1/1/2005	DENTON			2005-35383
TX	DENTON AND TARRANT	TX1210004.00	NORTEX MINERALS LP	1/1/2005
TX	DENTON AND TARRANT	TX1210005.00	NORTEX MINERALS LP	5/1/2003	DENTON			2004-124550
TX	DENTON AND TARRANT	TX1210005.00	NORTEX MINERALS LP		TARRANT			D203315430
TX	DENTON AND TARRANT	TX1210005.00	NORTEX MINERALS LP	5/1/2003
TX	DENTON AND TARRANT	TX1210005.00	NORTEX MINERALS LP
TX	DENTON AND TARRANT	TX1210005.00	NORTEX MINERALS LP
TX	DENTON AND TARRANT	TX1210005.00	NORTEX MINERALS LP	5/1/2003
TX	DENTON AND TARRANT	TX1210005.00	NORTEX MINERALS LP
TX	DENTON	TX1210006.00	PETERSON FAMILY TRUST ETAL	11/7/2006	DENTON			2006-137384
TX	DENTON	TX1210007.00	PATTERSON LOGISTICS SVC	8/20/2007	DENTON			2007-108522
TX	DENTON AND TARRANT	TX1210008.01	NORTEX MINERALS LP	4/30/2007	DENTON			2007-69391
TX	DENTON AND TARRANT	TX1210008.01	NORTEX MINERALS LP	4/30/2007
TX	DENTON	TX1210008.02	LEOLA W HUGG CHARITABLE TR	10/17/2006	DENTON			2006-141646
TX	DENTON AND TARRANT	TX1210010.01	NORTEX MINERALS LP	1/1/2005	DENTON			2005-35383
TX	DENTON AND TARRANT	TX1210010.01	NORTEX MINERALS LP	1/1/2005
TX	DENTON AND TARRANT	TX1210011.01	WAUNITA L CLARK	8/12/2001	DENTON	4931	1803	101800
TX	DENTON AND TARRANT	TX1210011.01	WAUNITA L CLARK	8/12/2001	TARRANT			D203174562
TX	DENTON AND TARRANT	TX1210011.01	WAUNITA L CLARK	8/12/2001
TX	DENTON AND TARRANT	TX1210011.01	WAUNITA L CLARK	8/12/2001
TX	DENTON AND TARRANT	TX1210011.01	WAUNITA L CLARK	8/12/2001

	DENTON AND TARRANT	TX1210011.01	WAUNITA L CLARK	8/12/2001
TX	DENTON AND TARRANT	TX1210011.02	LAURA BETH BRINKER	8/12/2001	DENTON	4931	1807	101801
TX	DENTON AND TARRANT	TX1210011.02	LAURA BETH BRINKER	8/12/2001	TARRANT			D203174564
TX	DENTON AND TARRANT	TX1210011.02	LAURA BETH BRINKER	8/12/2001
TX	DENTON AND TARRANT	TX1210011.02	LAURA BETH BRINKER	8/12/2001
TX	DENTON AND TARRANT	TX1210011.02	LAURA BETH BRINKER	8/12/2001
TX	DENTON AND TARRANT	TX1210011.02	LAURA BETH BRINKER	8/12/2001
TX	DENTON AND TARRANT	TX1210011.03	JACK CROWLEY ET AL	8/27/2001	DENTON	4931	1812	101802
TX	DENTON AND TARRANT	TX1210011.03	JACK CROWLEY ET AL	8/27/2001	TARRANT			D203174561
TX	DENTON AND TARRANT	TX1210011.03	JACK CROWLEY ET AL	8/27/2001
TX	DENTON AND TARRANT	TX1210011.03	JACK CROWLEY ET AL	8/27/2001
TX	DENTON AND TARRANT	TX1210011.03	JACK CROWLEY ET AL	8/27/2001
TX	DENTON AND TARRANT	TX1210011.03	JACK CROWLEY ET AL	8/27/2001
TX	DENTON AND TARRANT	TX1210011.03	JACK CROWLEY ET AL	8/27/2001
TX	DENTON AND TARRANT	TX1210011.03	JACK CROWLEY ET AL	8/27/2001
TX	DENTON AND TARRANT	TX1210012.01	DR WELLS O STEPHENS EST	12/17/2001	DENTON	5000	1164	4043
TX	DENTON AND TARRANT	TX1210012.01	DR WELLS O STEPHENS EST	12/17/2001	TARRANT			D202037586
TX	DENTON AND TARRANT	TX1210012.02	DR C B KENDALL EST	12/17/2001	DENTON	5000	1169	4044
TX	DENTON AND TARRANT	TX1210012.02	DR C B KENDALL EST	12/17/2001	TARRANT			D202037587
TX	DENTON	TX1210016.00	KENDRA STEPHENS ET AL	1/15/2008	DENTON			2008-27701
TX	DENTON	TX1210017.00	GLENN HYDE ET AL	4/5/2002	DENTON	5249	1757	4574
TX	DENTON	TX1210018.01	THE PROSPECT COMPANY	1/30/2009	DENTON			2009-19205

TX	DENTON	TX1210018.02	PETRUS INVESTMENT LP	9/15/2009	DENTON			2010-37198
TX	DENTON	TX1210018.04	TEXAS MOTOR SPEEDWAY INC	12/20/2011	DENTON			2012-25549
TX	DENTON	TX1210019.01	NORTH DALLAS BROKERS INC	5/5/2002	DENTON	5099	1112	69050
TX	DENTON	TX1210020.00	DOROTHY GEBERT	10/12/2001	DENTON	4988	5	137605
TX	DENTON	TX1210021.00	BUCHANAN PARTNERS LTD	11/1/2001	DENTON	4964	1854
TX	DENTON	TX1210021.00	BUCHANAN PARTNERS LTD	11/1/2001
TX	DENTON	TX1210021.00	BUCHANAN PARTNERS LTD	11/1/2001
TX	DENTON	TX1210023.00	LEWAYNE PETERSON TR ET AL	7/31/2006	DENTON			2006-94361
TX	DENTON AND TARRANT	TX1210024.01	NORTEX MINERALS LP	8/15/2005	DENTON			2006-21810
TX	DENTON AND TARRANT	TX1210024.01	NORTEX MINERALS LP	8/15/2005
TX	DENTON AND TARRANT	TX1210026.01	PBBM NORTHLAKE LTD	3/2/2009	DENTON			2009-60422
TX	DENTON AND TARRANT	TX1210026.01	PBBM NORTHLAKE LTD	3/2/2009
TX	DENTON AND TARRANT	TX1210026.01	PBBM NORTHLAKE LTD	3/2/2009
TX	DENTON AND TARRANT	TX1210026.01	PBBM NORTHLAKE LTD	3/2/2009
TX	DENTON	TX1210026.02	DEVON ENERGY PRODUCTION COMPANY LP	6/4/2012	DENTON			2012-68882
TX	DENTON	TX1210029.00	PETRUS INVESTMENT LP	9/15/2009	DENTON			2010-37199
TX	DENTON AND TARRANT	TX1210031.13	LUMINANT MINERAL DEVELOPMENT	3/2/2010	DENTON			2010-22559
TX	DENTON AND TARRANT	TX1210031.13	LUMINANT MINERAL DEVELOPMENT	3/2/2010	TARRANT			D210047137
TX	DENTON AND TARRANT	TX1210031.14	JOHN PORTER FARMS INC	4/21/2014	DENTON			2014-41356
TX	DENTON AND TARRANT	TX1210031.14	JOHN PORTER FARMS INC	4/21/2014	TARRANT			D214084785
TX	DENTON AND TARRANT	TX1210031.15	BOB CATES ET UX	4/23/2014	DENTON			2014-41354
TX	DENTON AND TARRANT	TX1210031.15	BOB CATES ET UX	4/23/2014	TARRANT			D214084785
TX	DENTON AND TARRANT	TX1210031.16	JOE CATES ET UX	4/23/2014	DENTON			2014-41355
TX	DENTON	TX1210031.17	RUSSELL C HOLLINGSWORTH ET UX	5/6/2014	DENTON			2014-49256
TX	DENTON	TX1210031.18	CARL BRASWELL ET UX	5/1/2014	DENTON			2014-41359

TX	DENTON	TX1210031.19	GRANT T DOSTERT ET UX	4/24/2014	DENTON	2014-49255
TX	DENTON AND TARRANT	TX1210031.20	PAUL D COPENHAVER JR ET UX	5/12/2014	DENTON	2014-49254
TX	DENTON	TX1210031.22	BARRY LEMONS ET UX	6/5/2014	DENTON	2014-77321
TX	DENTON	TX1210031.23	JAMES F HUNTER	6/11/2014	DENTON	2014-61289
TX	DENTON	TX1210031.24	CLYDE E WALL ET UX	7/7/2014	DENTON	2014-73371
TX	DENTON	TX1210031.25	DARIN G WINGER ET UX	7/9/2014	DENTON	2014-73372
TX	DENTON	TX1210031.26	PAUL J FLEURY ET UX	7/17/2014	DENTON	2014-77320
TX	DENTON AND TARRANT	TX1210031.27	JOHN MURLEY	7/24/2014	DENTON	2014-82676
TX	DENTON AND TARRANT	TX1210031.27	JOHN MURLEY	7/24/2014	TARRANT	D215142691
TX	DENTON AND TARRANT	TX1210031.28	SUE WORKS	5/16/2014	DENTON	2014-61290
TX	DENTON AND TARRANT	TX1210031.28	SUE WORKS	5/16/2014	TARRANT	D214132772
TX	DENTON	TX1210031.29	MARILYN L BOEMER	8/13/2014	TARRANT	D214195143
TX	DENTON AND TARRANT	TX1210031.30	PAUL A PINSON ET UX	8/13/2014	TARRANT	D214195144
TX	TARRANT	TX1210031.31	DEBORAH L FLORES	8/13/2014	TARRANT	D214195145
TX	DENTON AND TARRANT	TX1210031.32	WILLIAM A KIRK	8/18/2014	DENTON	2014-100907
TX	DENTON AND TARRANT	TX1210031.32	WILLIAM A KIRK	8/18/2014	TARRANT	D214195142
TX	DENTON	TX1210031.34	MARK ALLEN HUFF	8/9/2014	DENTON	2014-100906
TX	DENTON	TX1210031.35	CHAD DAVID REITHMEIER ET UX	8/29/2014	DENTON	2014-100905
TX	DENTON AND TARRANT	TX1210031.36	RICHARD N BROWN ET UX	6/26/2014	DENTON	2014-109197
TX	DENTON AND TARRANT	TX1210031.36	RICHARD N BROWN ET UX	6/26/2014	TARRANT	D214225480
TX	DENTON AND TARRANT	TX1210031.37	PAUL DON CRUSE ET UX	10/8/2014	DENTON	2014-109196
TX	DENTON AND TARRANT	TX1210031.37	PAUL DON CRUSE ET UX		TARRANT	D214225481
TX	DENTON AND TARRANT	TX1210031.39	KENNETH MILLER	10/16/2014	DENTON	2014-122345
TX	DENTON AND TARRANT	TX1210031.39	KENNETH MILLER	10/16/2014	TARRANT	D214256085
TX	DENTON	TX1210031.40	ROBERTA MARIE CRUSE	10/8/2014	DENTON	2014-109195

TX	DENTON AND TARRANT	TX1210031.41	LARRY CARSON TIDWELL ET UX	11/6/2014	DENTON	2015-1219
TX	DENTON AND TARRANT	TX1210031.41	LARRY CARSON TIDWELL ET UX	11/6/2014	TARRANT	D214275922
TX	DENTON AND TARRANT	TX1210031.46	RAYA NEVEEN REDDY ET UX	12/10/2014	DENTON	2015-1217
TX	DENTON AND TARRANT	TX1210031.46	RAYA NEVEEN REDDY ET UX	12/10/2014	TARRANT	D214275920
TX	DENTON	TX1210031.47	JOHNNY G GRACE ET UX	10/29/2014	DENTON	2015-1222
TX	TARRANT	TX1210031.48	MELISSA M TAYLOR ET VIR	11/11/2014	TARRANT	D214275921
TX	DENTON	TX1210031.49	JAMES R SOWELL ET UX	9/2/2014	DENTON	2015-1220
TX	DENTON AND TARRANT	TX1210031.52	JOHN T MASON	8/25/2014	DENTON	2015-8218
TX	DENTON AND TARRANT	TX1210031.52	JOHN T MASON	8/25/2014	TARRANT	D215013068
TX	DENTON AND TARRANT	TX1210031.53	SHERRY BUGG	10/24/2014	DENTON	2015-8217
TX	DENTON AND TARRANT	TX1210031.53	SHERRY BUGG	10/24/2014	TARRANT	D215013067
TX	DENTON AND TARRANT	TX1210031.56	JAMES R HAIRE ET UX	12/18/2014	DENTON	2015-14690
TX	DENTON AND TARRANT	TX1210031.56	JAMES R HAIRE ET UX		TARRANT	D215026331
TX	DENTON AND TARRANT	TX1210031.57	DALE GLEN & STELLA MARIE EDELMAN	1/21/2015	DENTON	2015-14688
TX	DENTON AND TARRANT	TX1210031.57	DALE GLEN & STELLA MARIE EDELMAN	1/21/2015	TARRANT	D215046447
TX	DENTON	TX1210031.58	RANDELL M DAY	1/6/2015	DENTON	2015-14689
TX	DENTON AND TARRANT	TX1210031.59	KEVIN SIMMONS	2/5/2015	DENTON	2015-26717
	DENTON AND TARRANT	TX1210031.59	KEVIN SIMMONS		TARRANT	D215046448
TX	DENTON AND TARRANT	TX1210031.60	ANGELA DAONNE RAWIE	8/19/2014	DENTON	2015-26718
	DENTON AND TARRANT	TX1210031.60	ANGELA DAONNE RAWIE		TARRANT	D215052665
TX	DENTON	TX1210031.64	CARRIE RENE RENDON	11/13/2014	DENTON	2015-60638
TX	DENTON	TX1210031.66	TIFFANY D MAYES ET AL	6/9/2015	DENTON	2015-117487
TX	DENTON	TX1210031.67	JERRY L SMART ET UX	12/5/2015	DENTON	PENDING
TX	DENTON	TX1210031.68	WILLIAM G BAKER	12/3/2015	DENTON	PENDING

TX	DENTON	TX1210031.69	JAMES E BROOME ET UX	12/3/2015	DENTON	PENDING
TX	DENTON	TX1210031.70	RICHARD A CIAMPA ET UX	12/2/2015	DENTON	PENDING
TX	DENTON	TX1210031.71	JASBIR SIDHU ET UX	12/7/2015	DENTON	PENDING
TX	DENTON	TX1210031.72	GARY ALLEN MIRON ET UX	12/7/2015	DENTON	PENDING
TX	DENTON	TX1210031.73	MARCIA J WIETING	12/4/2015	DENTON	PENDING
TX	DENTON	TX1210039.02	A & C CATTLE COMPANY LLC	8/19/2014	DENTON	2014-90016
TX	DENTON	TX1210044.00	PETRUS INVESTMENT LP	8/4/2010	DENTON	2010-89083
TX	DENTON	TX1210048.01	INTEL CORPORATION	9/23/2010	DENTON	2010-98249
TX	DENTON	TX1210051.01	ALLIANCE AIRPORT AUTHORITY INC	5/3/2011	DENTON	2011-42422
TX	DENTON	TX1210051.01	ALLIANCE AIRPORT AUTHORITY INC
TX	DENTON	TX1210052.00	HOWARD PETERSON IRREVOC TR	5/4/2011	DENTON	2011-42421
TX	DENTON	TX1210056.99	INTEL CORPORATION	10/25/2011	DENTON	2011-103169
TX	DENTON	TX1210060.01	ROXANNE HARMONSON DOLPH	9/19/2011	DENTON	2011-90979
TX	DENTON	TX1210060.02	MARIE PETTY ETHRIDGE	9/20/2011	DENTON	2011-93491
TX	DENTON	TX1210060.03	PETER C HARMONSON III	9/19/2011	DENTON	2011-93493
TX	DENTON	TX1210060.04	BOBBY KIRK HARMONSON	9/19/2011	DENTON	2011-93492
TX	DENTON	TX1210060.05	DAVID L HARMONSON	9/19/2011	DENTON	2011-93494
TX	DENTON	TX1210060.06	PAULA H DUNCAN	9/19/2011	DENTON	2011-93495
TX	DENTON	TX1210060.07	LEE ANN THOMAS MILLER	9/29/2011	DENTON	2011-102938
TX	DENTON	TX1210060.08	RITA CARMA LEE DAVIS	9/22/2011	DENTON	2011-102941
TX	DENTON	TX1210060.09	CATHERINE LYNN THOMAS HAMILTON	9/29/2011	DENTON	2011-102940
TX	DENTON	TX1210060.10	DAVID EDWIN LEE	9/28/2011	DENTON	2011-102939
TX	DENTON	TX1210060.11	NONA LOIS LEE STONE	9/22/2011	DENTON	2011-102935
TX	DENTON	TX1210060.12	WILLIAM S SWAN	9/30/2011	DENTON	2011-102936
TX	DENTON	TX1210060.13	LINDA THOMAS	10/11/2011	DENTON	2011-102937
TX	DENTON	TX1210060.14	MELBA JEAN LEE KOVICS	9/22/2011	DENTON	2011-104265
TX	DENTON	TX1210060.15	ROBERT EARL LEE	9/22/2011	DENTON	2011-104264
TX	DENTON	TX1210060.16	ARLIN LEE	9/29/2011	DENTON	2011-104263
TX	DENTON	TX1210060.17	LESLIE JO BALTON	10/18/2011	DENTON	2011-106798
TX	DENTON	TX1210060.18	PERRY VAN MOORE	10/20/2011	DENTON	2011-106797
TX	DENTON	TX1210060.20	ROBERT BEAMS	10/20/2011	DENTON	2011-106796
TX	DENTON	TX1210060.21	BETTY BELLAMY	10/20/2011	DENTON	2011-106791
TX	DENTON	TX1210060.22	J RUSSELL BELLAMY	10/20/2011	DENTON	2011-106792

TX	DENTON	TX1210060.23	RODNEY L LEE	9/29/2011	DENTON	2011-106793
TX	DENTON	TX1210060.24	IDELLA L MCFARLEN	10/24/2011	DENTON	2011-110028
TX	DENTON	TX1210060.25	OTIS E SMITH	10/24/2011	DENTON	2011-106794
TX	DENTON	TX1210060.26	RKJR PROPERTIES LTD	11/18/2011	DENTON	2011-113741
TX	DENTON	TX1210060.27	ROBERT HUFF MITCHELL C TRUST	11/18/2011	DENTON	2011-113740
TX	DENTON	TX1210060.28	JEAN EVELYN MITCHELL C TRUST	11/18/2011	DENTON	2011-113739
TX	DENTON	TX1210060.29	JOHN E GIBSON	11/1/2011	DENTON	2011-110026
TX	DENTON	TX1210060.30	LINDA W COLLINS	10/20/2011	DENTON	2011-110027
TX	DENTON	TX1210060.31	STEVEN LEE THOMAS	10/25/2011	DENTON	2011-110029
TX	DENTON	TX1210060.32	SUE WOOLDRIDGE	10/20/2011	DENTON	2011-110031
TX	DENTON	TX1210060.33	JANE REYNOLDS	10/20/2011	DENTON	2011-110030
TX	DENTON	TX1210060.34	CAROLYN WEST	11/11/2011	DENTON	2011-113738
TX	DENTON	TX1210060.35	JACK E SMITH	11/7/2011	DENTON	2011-113743
TX	DENTON	TX1210060.36	STAN COMBEST ET UX	10/5/2011	DENTON	2011-113742
TX	DENTON	TX1210060.37	SHARON R VANDERGRIFT	11/17/2011	DENTON	2011-117400
TX	DENTON	TX1210060.38	CYNTHIA RAINEY YEWELL ET AL	12/13/2011	DENTON	2012-910
TX	DENTON	TX1210060.39	KENNETH WAYNE RAINEY	12/13/2011	DENTON	2012-909
TX	DENTON	TX1210060.40	JENNIFER R RAINEY ESTATE	12/13/2011	DENTON	2012-908
TX	DENTON	TX1210060.41	FW SPORTS AUTHORITY INC	12/20/2011	DENTON	2011-121883
TX	DENTON	TX1210060.42	THE PROSPECT COMPANY	11/10/2011	DENTON	2012-4688
TX	DENTON	TX1210060.43	FRANKIE JO LEE ROBBINS ET AL	2/15/2011	DENTON	2011-22216
TX	DENTON	TX1210060.44	CITY OF FORT WORTH	8/24/2012	DENTON	2012-108148
TX	DENTON	TX1210060.45	TEXAS MOTOR SPEEDWAY INC	3/7/2013	DENTON	2013-39639
TX	DENTON	TX1210060.46	ST TX MF-115929	11/5/2013	DENTON	2013-143751
TX	DENTON	TX1210060.47	MONTE CLAMPITT	6/27/2013	DENTON	2013-143747
TX	DENTON	TX1210060.48	MARK MCADAMS	7/9/2013	DENTON	2013-143749
TX	DENTON	TX1210060.49	MARCELLA P STRICKLAND	7/9/2013	DENTON	2013-143750
TX	DENTON	TX1210060.50	MARSHA A CRAWFORD	7/9/2013	DENTON	2013-143748
TX	DENTON	TX1210060.51	JAMES E PEPPER	7/9/2013	DENTON	2014-1197
TX	DENTON	TX1210060.52	BUCHANAN PARTNERS LTD	7/1/2014	DENTON	2014-73370
TX	DENTON	TX1210060.53	PETRUS INVESTMENT LP	4/22/2014	DENTON	2014-49248
TX	DENTON	TX1210066.01	LAHONDA JO PETERSON	5/12/2010	DENTON	2010-55825
TX	DENTON	TX1210066.01	LAHONDA JO PETERSON	5/12/2010
TX	DENTON	TX1210066.02	TRUETT WELDON PETERSON	5/12/2010	DENTON	2010-60220
TX	DENTON	TX1210066.02	TRUETT WELDON PETERSON

TX	DENTON	TX1210067.00	BLM TX NM-101032	9/1/1998	DENTON
TX	DENTON	TX1210069.00	GLORIA HAMMACK REV TRUST ET AL	6/1/2006	DENTON	2006-81898
TX	DENTON	TX1210071.00	ST TX MF-114704	1/8/2013	DENTON	2013-14110
TX	DENTON	TX1210072.01	NORTEX MINERALS LP	3/1/2013	DENTON	2013-21369
TX	DENTON	TX1210074.00	WILLIAMS QUALITY RENTAL LLC	8/5/2013	DENTON	2013-111254
TX	DENTON	TX1210075.00	AHMAD FAMILY PARTNERSHIP	1/9/2014	DENTON	2014-3716
TX	DENTON	TX1210079.00	RUSSELL E HALL ET UX	4/23/2014	DENTON	2014-41360
TX	DENTON	TX1210083.00	RAYMOND MICHAEL CHARLEY	12/3/2015	DENTON	PENDING
TX	DENTON AND TARRANT	TX4390481.00	NORTEX MINERALS LP	9/1/2005	DENTON	2008-51627
TX	DENTON AND TARRANT	TX4390481.00	NORTEX MINERALS LP	9/1/2005	TARRANT	D206181584
TX	DENTON AND TARRANT	TX4390481.00	NORTEX MINERALS LP	9/1/2005
TX	DENTON AND TARRANT	TX4390481.00	NORTEX MINERALS LP	9/1/2005
TX	DENTON AND TARRANT	TX4390481.00	NORTEX MINERALS LP	9/1/2005
TX	DENTON AND TARRANT	TX4390481.00	NORTEX MINERALS LP	9/1/2005
TX	DENTON AND TARRANT	TX4390499.01	ANNE CARTWRIGHT FAMILY TR	3/18/2003	DENTON	2008-65818
TX	DENTON AND TARRANT	TX4390499.01	ANNE CARTWRIGHT FAMILY TR		TARRANT	D203127485
TX	DENTON AND TARRANT	TX4390499.02	VICTORIA NEWTON TR	3/15/2003	DENTON	2008-65819
TX	DENTON AND TARRANT	TX4390499.02	VICTORIA NEWTON TR	3/15/2003	TARRANT	D203325911
TX	DENTON AND TARRANT	TX4390499.03	ELIZABETH P CARVER ESTATE	3/15/2003	DENTON	2008-65820
TX	DENTON AND TARRANT	TX4390499.03	ELIZABETH P CARVER ESTATE	3/15/2003	TARRANT	D203325910
TX	DENTON AND TARRANT	TX4390499.04	JEROME CARTWRIGHT IND	3/18/2003	DENTON	2008-65821
TX	DENTON AND TARRANT	TX4390499.04	JEROME CARTWRIGHT IND	3/18/2003	TARRANT	D203127484
TX	DENTON AND TARRANT	TX4390499.05	JEAN CARTWRIGHT DICKSON	3/18/2003	DENTON	2008-65822
TX	DENTON AND TARRANT	TX4390499.05	JEAN CARTWRIGHT DICKSON	3/18/2003	TARRANT	D203127483

TX	DENTON AND TARRANT	TX4390481.00	NORTEX MINERALS LP	9/1/2005	DENTON	2008-51627
TX	DENTON AND TARRANT	TX4390481.00	NORTEX MINERALS LP	9/1/2005	TARRANT	D206181584
TX	DENTON AND TARRANT	TX4390481.00	NORTEX MINERALS LP	9/1/2005		2008-51627
TX	DENTON AND TARRANT	TX4390481.00	NORTEX MINERALS LP	9/1/2005		2008-51627
TX	DENTON AND TARRANT	TX4390481.00	NORTEX MINERALS LP	9/1/2005		2008-51627
TX	DENTON AND TARRANT	TX4390481.00	NORTEX MINERALS LP	9/1/2005		2008-51627
TX	DENTON AND TARRANT	TX4390921.00	MOUNT OLIVET CEMETERY ASSN	8/3/2009	TARRANT	D209208077
TX	DENTON AND TARRANT	TX4390921.00	MOUNT OLIVET CEMETERY ASSN	8/3/2009	DENTON	2009-95113

Exhibit A, Page 25

3230471v2

PORTIONS OF THIS EXHIBIT DENOTED WITH THREE ASTERISKS (***) HAVE BEEN OMITTED PURSUANT TO A REQUEST FOR CONFIDENTIAL TREATMENT

EXHIBIT B

to the

GAS GATHERING AGREEMENT

[ALLIANCE AREA]

RECEIPT POINTS AND DELIVERY POINTS

This Exhibit B is attached to the Gas Gathering Agreement (the “Agreement”) dated as of April 1, 2016, by and between BlueStone Natural Resources II, LLC, as Producer, and Cowtown Pipeline Partners L.P., as Gatherer, and made a part thereof for all purposes. All defined terms used herein shall have the same meaning as set forth in the Agreement.

Gathering System Receipt Point(s)

Ownership	Sales Meter Name	Meter #	Active?
CMLP/QRI	AA BREWER UNIT NORTH 14H	AL35467	Active
CMLP/QRI	AA BREWER UNIT NORTH 15H	AL35470	Active
CMLP/QRI	AA BREWER UNIT NORTH 16H	AL35472	Active
CMLP/QRI	AA BREWER UNIT NORTH 17H	AL35473	Active
CMLP/QRI	AA BREWER UNIT R 2H	AL35331	Active
CMLP/QRI	AA BREWER UNIT R 3H	AL35332	Active
CMLP/QRI	AA BREWER UNIT R 4H	AL35333	Active
CMLP/QRI	AA BREWER UNIT R 5H	AL35334	Active
CMLP/QRI	AA BREWER UNIT R 6H	AL35335	Active
QRI	AA BREWER UNIT SOUTH 7H	AL35474	Active
CMLP/QRI	AA BREWER UNIT SOUTH 8H	AL35479	Active
QRI	AA BREWER UNIT SOUTH 9H	AL35475	Active
CMLP/QRI	AA BREWER UNIT SOUTH 10H	AL35480	Active
CMLP/QRI	AA BREWER UNIT SOUTH 11H	AL35476	Active
CMLP/QRI	AA BREWER UNIT SOUTH 12H	AL35477	Active
CMLP/QRI	AA BREWER UNIT SOUTH 13H	AL35481	Active
CMLP/QRI	AIRPORT ACREY NORTH 1H	AL36409	Active

Exhibit B, Page 1

PORTIONS OF THIS EXHIBIT DENOTED WITH THREE ASTERISKS (***) HAVE BEEN OMITTED PURSUANT TO A REQUEST FOR CONFIDENTIAL TREATMENT

Ownership	Sales Meter Name	Meter #	Active?
CMLP/QRI	AIRPORT ACREY NORTH 2H	AL36411	Active
CMLP/QRI	AIRPORT ACREY NORTH 3H	AL36412	Active
CMLP/QRI	AIRPORT ACREY NORTH 4H	AL36413	Active
CMLP/QRI	AIRPORT ACREY NORTH 5H	AL36397	Active
CMLP/QRI	AIRPORT ACREY SOUTH 1H	AL34647	Active
CMLP/QRI	AIRPORT ACREY SOUTH 2H	AL34649	Active
CMLP/QRI	AIRPORT ACREY SOUTH 3H	AL34650	Active
CMLP/QRI	AIRPORT ACREY SOUTH 4H	AL34654	Active
CMLP/QRI	AIRPORT ACREY SOUTH 5H	AL34659	Active
CMLP/QRI	ALLIANCE AIRPORT 1H	AL31897	Active
CMLP/QRI	ALLIANCE AIRPORT 2H	AL32800	Active
CMLP/QRI	ALLIANCE AIRPORT 3H	AL34277	Active
CMLP/QRI	ALLIANCE AIRPORT KS UNIT 1H	AL34130	Active
CMLP/QRI	ALLIANCE AIRPORT KS UNIT 3H	AL17240	Active
CMLP/QRI	ALLIANCE AIRPORT KS UNIT 5H	AL17242	Active
CMLP/QRI	ALLIANCE AIRPORT KS UNIT 7H	AL17244	Active
QRI	ALLIANCE AIRPORT KS UNIT 9H	AL35500	Active
CMLP/QRI	ALLIANCE AIRPORT KS UNIT 10H	AL35504	Active
CMLP/QRI	ALLIANCE AIRPORT KS UNIT 11H	AL35503	Active
CMLP/QRI	ALLIANCE AIRPORT KS UNIT 20H	AL34175	Active
CMLP/QRI	ALLIANCE AIRPORT KS UNIT 21H	AL34176	Active
CMLP	ALLIANCE B 2H	AL32309	Active
CMLP/QRI	ALLIANCE B 3H	AL32310	Active
CMLP/QRI	ALLIANCE B 5H	AL33098	Active

Exhibit B, Page 2

PORTIONS OF THIS EXHIBIT DENOTED WITH THREE ASTERISKS (***) HAVE BEEN OMITTED PURSUANT TO A REQUEST FOR CONFIDENTIAL TREATMENT

Ownership	Sales Meter Name	Meter #	Active?
CMLP/QRI	ALLIANCE B 6H	AL33571	Active
CMLP	ALLIANCE B 7H	AL33572	Active
CMLP/QRI	ALLIANCE B 8H	AL33573	Active
CMLP/QRI	ALLIANCE B 9H	AL33574	Active
CMLP/QRI	ALLIANCE B 10H	AL33575	Active
CMLP/QRI	ALLIANCE B 11H	AL33576	Active
CMLP/QRI	ALLIANCE B 12H	AL33577	Active
CMLP/QRI	ALLIANCE C 1H	AL30661	Active
CMLP/QRI	ALLIANCE C 2H	AL30660	Active
CMLP/QRI	ALLIANCE C 3H	AL33495	Active
CMLP/QRI	ALLIANCE C 4H	AL33496	Active
CMLP/QRI	ALLIANCE C 5H	AL33497	Active
CMLP/QRI	ALLIANCE C 6H	AL33498	Active
CMLP/QRI	ALLIANCE C 7H	AL33499	Active
CMLP	ALLIANCE COMMERCE A 1H SALES	AL33164	Active
CMLP	ALLIANCE COMMERCE A 2H SALES	AL33165	Active
CMLP	ALLIANCE COMMERCE A 3H SALES	AL33163	Active
CMLP/QRI	ALLIANCE COMMERCE B 1H	AL33247	Active
CMLP/QRI	ALLIANCE COMMERCE B 2H	AL33251	Active
CMLP/QRI	ALLIANCE COMMERCE B 3H	AL34254	Active
CMLP/QRI	ALLIANCE COZART 1H	AL31085	Active
CMLP/QRI	ALLIANCE COZART 2H	AL32650	Active
CMLP/QRI	ALLIANCE COZART 3H	AL34722	Active
CMLP	ALLIANCE COZART 4H	AL34723	Active

Exhibit B, Page 3

PORTIONS OF THIS EXHIBIT DENOTED WITH THREE ASTERISKS (***) HAVE BEEN OMITTED PURSUANT TO A REQUEST FOR CONFIDENTIAL TREATMENT

Ownership	Sales Meter Name	Meter #	Active?
CMLP	ALLIANCE CWN 13H (CARTWRIGHT NORTH UNIT 13)	AL18768	Active
QRI	ALLIANCE CWN 1H	AL31790	Active
CMLP/QRI	ALLIANCE CWN 2H	AL31791	Active
CMLP/QRI	ALLIANCE D 1H	AL32247	Active
CMLP/QRI	ALLIANCE D 2H	AL32248	Active
CMLP/QRI	ALLIANCE D 3H	AL33101	Active
CMLP/QRI	ALLIANCE D 4H	AL33175	Active
CMLP/QRI	ALLIANCE D 5H	AL33630	Active
CMLP/QRI	ALLIANCE D 6H	AL33627	Active
CMLP/QRI	ALLIANCE D 7H	AL33628	Active
CMLP/QRI	ALLIANCE D 8H	AL33629	Active
CMLP/QRI	ALLIANCE D 9H	AL33631	Active
CMLP/QRI	ALLIANCE D 10H	AL33633	Active
CMLP/QRI	ALLIANCE D 11H	AL33634	Active
CMLP/QRI	ALLIANCE D 12H	AL33642	Active
CMLP/QRI	ALLIANCE E 1H	AL32418	Active
CMLP/QRI	ALLIANCE E 3H	AL33640	Active
CMLP/QRI	ALLIANCE E 4H	AL33645	Active
CMLP/QRI	ALLIANCE E 5H	AL33644	Active
CMLP/QRI	ALLIANCE E 6H	AL33641	Active
CMLP/QRI	ALLIANCE F 1H	AL30956	Active
CMLP/QRI	ALLIANCE F 3H	AL33806	Active
CMLP/QRI	ALLIANCE F 4H	AL33831	Active
CMLP/QRI	ALLIANCE F 5H	AL33803	Active

Exhibit B, Page 4

PORTIONS OF THIS EXHIBIT DENOTED WITH THREE ASTERISKS (***) HAVE BEEN OMITTED PURSUANT TO A REQUEST FOR CONFIDENTIAL TREATMENT

Ownership	Sales Meter Name	Meter #	Active?
CMLP/QRI	ALLIANCE FLOREN 1	AL20188	Active
CMLP/QRI	ALLIANCE GRAPHICS 1H	AL32909	Active
CMLP/QRI	ALLIANCE GRAPHICS 2H	AL32910	Active
CMLP/QRI	ALLIANCE GRAPHICS 3H	AL33346	Active
CMLP/QRI	ALLIANCE GRAPHICS 4H	AL33352	Active
CMLP/QRI	ALLIANCE GRAPHICS 5H	AL33846	Active
CMLP/QRI	ALLIANCE GRAPHICS 6H	AL33853	Active
CMLP/QRI	ALLIANCE GRAPHICS 7H	AL33848	Active
CMLP/QRI	ALLIANCE GRAPHICS 8H	AL34124	Active
CMLP/QRI	ALLIANCE GWS 1H	AL31508	Active
CMLP/QRI	ALLIANCE HUGG UNIT 1H	AL33056	Active
CMLP/QRI	ALLIANCE HUGG UNIT 2H	AL33057	Active
CMLP/QRI	ALLIANCE HUGG UNIT 3H	AL33055	Active
CMLP/QRI	ALLIANCE HUGG UNIT 8H	AL33739	Active
CMLP/QRI	ALLIANCE HUGG UNIT 9H	AL33737	Active
CMLP/QRI	ALLIANCE HUGG UNIT 10H	AL33738	Active
CMLP/QRI	ALLIANCE HUGG UNIT 4H	AL17409	Active
CMLP/QRI	ALLIANCE HUGG UNIT 6H	AL17411	Active
CMLP/QRI	ALLIANCE K 1H	AL31828	Active
CMLP/QRI	ALLIANCE K 2H	AL31829	Active
CMLP	ALLIANCE K 3H	AL33955	Active
CMLP/QRI	ALLIANCE K 4H	AL33956	Active
CMLP/QRI	ALLIANCE K UNIT 3H	AL34023	Active
CMLP/QRI	ALLIANCE K UNIT 4H	AL34024	Active

Exhibit B, Page 5

PORTIONS OF THIS EXHIBIT DENOTED WITH THREE ASTERISKS (***) HAVE BEEN OMITTED PURSUANT TO A REQUEST FOR CONFIDENTIAL TREATMENT

Ownership	Sales Meter Name	Meter #	Active?
CMLP/QRI	ALLIANCE K UNIT 5H	AL34021	Active
CMLP/QRI	ALLIANCE L 1H	AL31646	Active
CMLP/QRI	ALLIANCE L 2H	AL33407	Active
CMLP/QRI	ALLIANCE L 3H	AL33408	Active
CMLP/QRI	ALLIANCE L 4H	AL33406	Active
CMLP/QRI	ALLIANCE L 5H	AL33405	Active
CMLP/QRI	ALLIANCE LAU D 13H	AL34017	Active
CMLP/QRI	ALLIANCE M 1H	AL32799	Active
CMLP/QRI	ALLIANCE SARATOGA A 3H	AL33969	Active
CMLP	ALLIANCE SARATOGA A 4H	AL33975	Active
CMLP/QRI	ALLIANCE SARATOGA A 5H	AL33976	Active
CMLP/QRI	ALLIANCE SARATOGA A 6H	AL33984	Active
CMLP/QRI	ALLIANCE SARATOGA A 7H	AL34020	Active
CMLP/QRI	ALLIANCE SARATOGA A 8H	AL33977	Active
CMLP/QRI	ALLIANCE SARATOGA A 10H	AL33979	Active
CMLP/QRI	ALLIANCE SARATOGA A 11H	AL33980	Active
CMLP/QRI	ALLIANCE SARATOGA A 13H	AL33982	Active
CMLP/QRI	ALLIANCE SARATOGA A 14H	AL33983	Active
CMLP/QRI	ALLIANCE SARATOGA B 2H	AL32630	Active
CMLP/QRI	ALLIANCE SARATOGA B 3H	AL34054	Active
CMLP/QRI	ALLIANCE SARATOGA B 4H	AL34055	Active
CMLP/QRI	ALLIANCE SARATOGA B 5H	AL34056	Active
QRI	ALLIANCE SARATOGA B 7H	AL34026	Active
CMLP/QRI	ALLIANCE SARATOGA B 8H	AL34057	Active

Exhibit B, Page 6

PORTIONS OF THIS EXHIBIT DENOTED WITH THREE ASTERISKS (***) HAVE BEEN OMITTED PURSUANT TO A REQUEST FOR CONFIDENTIAL TREATMENT

Ownership	Sales Meter Name	Meter #	Active?
CMLP/QRI	ALLIANCE SARATOGA B 9H	AL34065	Active
CMLP/QRI	ALLIANCE SPEEDWAY A 1H	AL33764	Active
CMLP/QRI	ALLIANCE SPEEDWAY A 3H	AL33766	Active
CMLP/QRI	ALLIANCE SPEEDWAY A 5H	AL33767	Active
CMLP/QRI	ALLIANCE SPEEDWAY A 7H	AL33769	Active
CMLP/QRI	ALLIANCE SPEEDWAY C 2H	AL33807	Active
CMLP/QRI	ALLIANCE SPEEDWAY C 3H	AL33808	Active
CMLP	ALLIANCE SPEEDWAY C 4H	AL33809	Active
CMLP/QRI	ALLIANCE SPEEDWAY C 5H	AL33810	Active
CMLP/QRI	ALLIANCE SPEEDWAY C 6H	AL33811	Active
CMLP/QRI	ALLIANCE SPEEDWAY C 7H	AL33812	Active
CMLP/QRI	ALLIANCE SPEEDWAY C 8H	AL33815	Active
CMLP/QRI	ALLIANCE SPEEDWAY C 9H	AL33813	Active
CMLP/QRI	ALLIANCE SPEEDWAY C 10H	AL33814	Active
CMLP/QRI	ALLIANCE SPEEDWAY C 11H	AL33816	Active
CMLP/QRI	ALLIANCE TCA 1H (TECH CENTER A-1H)	AL32655	Active
CMLP/QRI	ALLIANCE TCA 2H (TECH CENTER A-2H)	AL33716	Active
CMLP/QRI	ALLIANCE TCB 2H (TECH CENTER B-2H)	AL32654	Active
CMLP/QRI	ALLIANCE TCB 3H (TECH CENTER B-3H)	AL33097	Active
CMLP/QRI	ALLIANCE TCB 4H (TECH CENTER B-4H)	AL33721	Active
CMLP/QRI	ALLIANCE TCB 5H (TECH CENTER B-5H)	AL33722	Active
CMLP/QRI	ALLIANCE TCB 6H (TECH CENTER B-6H)	AL33724	Active
CMLP/QRI	ALLIANCE TCB 7H (TECH CENTER B-7H)	AL33726	Active
CMLP/QRI	ALLIANCE TCN 1H (TECH CENTER NORTH 1H)	AL32721	Active

Exhibit B, Page 7

PORTIONS OF THIS EXHIBIT DENOTED WITH THREE ASTERISKS (***) HAVE BEEN OMITTED PURSUANT TO A REQUEST FOR CONFIDENTIAL TREATMENT

Ownership	Sales Meter Name	Meter #	Active?
CMLP/QRI	ALLIANCE TCN 2H (TECH CENTER NORTH 2H)	AL32722	Active
CMLP/QRI	ALLIANCE TCN 3H (TECH CENTER NORTH 3H)	AL32723	Active
CMLP/QRI	ALLIANCE TCS 1H (TECH CENTER SOUTH 1H)	AL32740	Active
CMLP/QRI	ALLIANCE TCS 2H (TECH CENTER SOUTH 2H)	AL32816	Active
QRI	ALLIANCE TCS 3H (TECH CENTER SOUTH 3H)	AL33255	Active
CMLP/QRI	ALLIANCE TCS 4H (TECH CENTER SOUTH 4H)	AL33256	Active
CMLP/QRI	ALLIANCE TCS 5H	AL33752	Active
CMLP/QRI	ALLIANCE TCS 6H	AL33758	Active
CMLP	ALLIANCE TCS 7H	AL33753	Active
CMLP/QRI	ALLIANCE TCS 8H (TECH CENTER SOUTH 8H)	AL33754	Active
QRI	ALLIANCE TMS B 4H	AL19088	Active
QRI	ALLIANCE TMS B 6H	AL19089	Active
QRI	ALLIANCE TMS B 8H	AL19090	Active
QRI	ALLIANCE TMS B 10H	AL19091	Active
CMLP	ALLIANCE TMS B 12H	AL19092	Active
CMLP/QRI	ALLIANCE TMS C 14H	AL19099	Active
CMLP/QRI	ALLIANCE TMS C 16H	AL19100	Active
CMLP/QRI	ALLIANCE TMS C 18H	AL19101	Active
CMLP	ALLIANCE TMS UNIT 1H	AL19148	Active
CMLP	ALLIANCE TMS UNIT 2H	AL19087	Active
CMLP	ALLIANCE TMS UNIT 8H	AL19149	Active
CMLP	ALLIANCE TMS UNIT 10H	AL19150	Active
CMLP/QRI	ALLIANCE WEST SPEEDWAY 1H	AL34010	Active
CMLP/QRI	ALLIANCE WEST SPEEDWAY 2H	AL34011	Active

Exhibit B, Page 8

PORTIONS OF THIS EXHIBIT DENOTED WITH THREE ASTERISKS (***) HAVE BEEN OMITTED PURSUANT TO A REQUEST FOR CONFIDENTIAL TREATMENT

Ownership	Sales Meter Name	Meter #	Active?
CMLP/QRI	ALLIANCE WEST SPEEDWAY 3H	AL34012	Active
CMLP/QRI	ALLIANCE WEST SPEEDWAY 4H	AL34013	Active
CMLP/QRI	ALLIANCE WEST SPEEDWAY 5H	AL34014	Active
CMLP/QRI	ALLIANCE WEST SPEEDWAY 6H	AL34015	Active
CMLP/QRI	ALLIANCE WEST SPEEDWAY 7H	AL34016	Active
CMLP/QRI	CARTWRIGHT 1H	AL31305	Active
CMLP/QRI	CARTWRIGHT 2H	AL31478	Active
CMLP/QRI	CARTWRIGHT A 1H	AL32233	Active
CMLP/QRI	CROSSING J 1H (ALPHA UNIT J-1H)	AL31598	Active
CMLP/QRI	CROSSING J 2H	AL34127	Active
CMLP/QRI	CROSSING UNIT A 1H (ALPHA UNIT A-1H)	AL31752	Active
CMLP/QRI	CROSSING UNIT A 3H	AL34217	Active
QRI	CROSSING UNIT A 4H	AL34222	Active
CMLP/QRI	CROSSING UNIT A 5H	AL34370	Active
CMLP/QRI	CROSSING UNIT A 6H	AL34228	Active
CMLP/QRI	CROSSING UNIT A 7H	AL34227	Active
CMLP/QRI	CROSSING UNIT B 2H (ALPHA UNIT B-2H)	AL31895	Active
CMLP/QRI	CROSSING UNIT B 3H (ALPHA UNIT B-3H)	AL31896	Active
CMLP/QRI	CROSSING UNIT B 4H	AL34223	Active
CMLP/QRI	CROSSING UNIT B 5H	AL34224	Active
CMLP/QRI	CROSSING UNIT B 6H	AL34225	Active
CMLP/QRI	CROSSING UNIT G 1H (ALPHA UNIT G-1H)	AL31443	Active
CMLP/QRI	CROSSING UNIT G 2H (ALPHA UNIT G-2H)	AL32304	Active
CMLP/QRI	CROSSING UNIT G 3H	AL32303	Active

Exhibit B, Page 9

PORTIONS OF THIS EXHIBIT DENOTED WITH THREE ASTERISKS (***) HAVE BEEN OMITTED PURSUANT TO A REQUEST FOR CONFIDENTIAL TREATMENT

Ownership	Sales Meter Name	Meter #	Active?
CMLP/QRI	CROSSING UNIT G 4H	AL34129	Active
CMLP/QRI	CROSSING UNIT G 6H	AL34165	Active
CMLP/QRI	CROSSING UNIT G 7H	AL34166	Active
CMLP/QRI	CROSSING UNIT G 8H	AL34169	Active
CMLP/QRI	CROSSING UNIT G 9H	AL34170	Active
CMLP/QRI	CROSSING UNIT H 1H	AL31160	Active
CMLP/QRI	CROSSING UNIT H 2H (ALPHA UNIT H-2H)	AL31161	Active
CMLP/QRI	CROSSING UNIT H 3H (ALPHA UNIT H-3H)	AL32945	Active
CMLP/QRI	CROSSING UNIT H 4H (ALPHA UNIT H-4H)	AL32946	Active
CMLP/QRI	CROSSING UNIT H 5H	AL34167	Active
CMLP/QRI	CROSSING UNIT H 6H	AL34168	Active
CMLP/QRI	CROSSING UNIT H 7H	AL34099	Active
CMLP/QRI	CROSSING UNIT H 8H	AL34100	Active
CMLP/QRI	CROSSING UNIT H 9H	AL34101	Active
CMLP/QRI	CROSSING UNIT N 3H (ALPHA UNIT N-3H)	AL31899	Active
CMLP/QRI	CROSSING UNIT R 2H	AL34237	Active
CMLP/QRI	CROSSING UNIT R 3H	AL34244	Active
CMLP/QRI	CROSSING UNIT S 2H (ALPHA UNIT S-2H)	AL31754	Active
CMLP/QRI	GATEWAY 1H	AL32490	Active
CMLP/QRI	GATEWAY 1 CARTWRIGHT UNIT 4H	AL34090	Active
CMLP/QRI	GATEWAY UNIT 1H	AL32491	Active
CMLP/QRI	OLIVET WEST UNIT 3H	AL34532	Active
CMLP/QRI	OLIVET WEST UNIT 4H	AL34531	Active
CMLP	ROBBINS FEDERAL 2H	AL19125	Active

Exhibit B, Page 10

PORTIONS OF THIS EXHIBIT DENOTED WITH THREE ASTERISKS (***) HAVE BEEN OMITTED PURSUANT TO A REQUEST FOR CONFIDENTIAL TREATMENT

Ownership	Sales Meter Name	Meter #	Active?
CMLP	ROBBINS FEDERAL 6H	AL19128	Active
CMLP/QRI	DEVON ALBRIGHT 1H CDP	AL21122	Active
CMLP	AIRPORT ACREY UNIT 6H/OLIVET CK (Olivet Sales)	AL21174	Inactive
CMLP	ALLIANCE A 1-4 SALES	AL21014	Inactive
CMLP	ALLIANCE B 1H	AL32308	Inactive
CMLP	ALLIANCE B-4H	AL32781	Inactive
CMLP/QRI	ALLIANCE E 2H	AL32419	Inactive
CMLP/QRI	ALLIANCE F 2H	AL30955	Inactive
CMLP/QRI	ALLIANCE HUGG UNIT 11H	AL17906	Inactive
QRI	ALLIANCE SARATOGA A 1H	AL30940	Inactive
CMLP	ALLIANCE SARATOGA A 2H	AL30939	Inactive
QRI	ALLIANCE SARATOGA B 1H	AL31155	Inactive
CMLP	CROSSING UNIT G-5H	AL34147	Inactive
CMLP/QRI	CROSSING UNIT S 1H (ALPHA UNIT S-1H)	AL31753	Inactive
CMLP	EAGLE MEADOWS	AL21126	Inactive
QRI	ALLIANCE AA BREWER UNIT 19	ST30658	Inactive
QRI	ALLIANCE SPEEDWAY UNIT C 1	DSPEEDC1	Inactive
QRI	ALLIANCE AIRPORT ACREY UNIT 6H	DACREY6H	Inactive

*To the extent the parties hereto have inadvertently omitted a Dedicated Property, such property shall be deemed covered under this Agreement and shall be included in this Exhibit B.

Delivery Point(s) to Transporter

Exhibit B, Page 11

PORTIONS OF THIS EXHIBIT DENOTED WITH THREE ASTERISKS (***) HAVE BEEN OMITTED PURSUANT TO A REQUEST FOR CONFIDENTIAL TREATMENT

Delivery Point	Transporter	Meter
Crosstex/Enlink	Crosstex North Texas Pipeline	70-50-031
Energy Transfer	Energy Transfer Paris Loop Pipeline	9835

Exhibit B, Page 12

PORTIONS OF THIS EXHIBIT DENOTED WITH THREE ASTERISKS (***) HAVE BEEN OMITTED PURSUANT TO A REQUEST FOR CONFIDENTIAL TREATMENT

EXHIBIT C

to the

GAS GATHERING AGREEMENT

[ALLIANCE AREA]

DEHYDRATION AND CO2 TREATING SERVICES

This Exhibit C is attached to the Gas Gathering Agreement (the “Agreement”) dated as of April 1, 2016, by and between BlueStone Natural Resources II, LLC, as Producer, and Cowtown Pipeline Partners L.P., as Gatherer, and made a part thereof for all purposes. All defined terms used herein shall have the same meaning as set forth in the Agreement.

Dehydration and CO2 Treating Services

The dehydration and CO2 treating services contemplate receiving the Subject Gas at the inlet flange of the applicable dehydration and/or CO2 treating facilities with the following specifications:

CO2 of less than 3.5% by volume;

and delivering the Subject Gas at the outlet flange of the applicable dehydration and/or CO2 treating facilities with the following specifications:

CO2 of less than 2.0% by volume, and

Not more than 7 pounds of water vapor per MMcf.

Exhibit C, Page 1 of 1

EX-10.4

PORTIONS OF THIS EXHIBIT DENOTED WITH THREE ASTERISKS (***) HAVE BEEN OMITTED PURSUANT TO A REQUEST FOR CONFIDENTIAL TREATMENT

Exhibit 10.4

Gas Gathering and Processing Agreement

Between

BLUESTONE NATURAL RESOURCES II, LLC,

COWTOWN PIPELINE PARTNERS L.P.

and

COWTOWN GAS PROCESSING PARTNERS L.P.

Cowtown Gas Facilities

TABLE OF CONTENTS

ARTICLE I DEFINITIONS    1

ARTICLE II DEDICATION    8

ARTICLE III RESERVATIONS OF PARTIES    9

ARTICLE IV GATHERING SYSTEM DELIVERY POINT(S), PLANT DELIVERY POINT(S) AND PRESSURE    10

ARTICLE V REGULATION OF PRODUCTION    12

ARTICLE VI QUANTITY    12

ARTICLE VII QUALITY    13

ARTICLE VIII TESTS    16

ARTICLE IX MEASUREMENT AND METER TESTING    17

ARTICLE X ALLOCATION PROCEDURE    19

ARTICLE XI DISPOSITION OF PRODUCER'S PORTION OF PLANT PRODUCTS    20

ARTICLE XII GATHERING AND PROCESSING FEES    20

ARTICLE XIII DISPOSITION OF PRODUCER'S PORTION OF RESIDUE GAS    21

ARTICLE XIV ACCOUNTING. PAYMENTS AND CREDIT ASSURANCES    21

ARTICLE XV WARRANTY    24

ARTICLE XVI TAXES    24

ARTICLE XVII INDEMNITY    24

ARTICLE XVIII FORCE MAJEURE    27

ARTICLE XIX UNPROFITABLE OPERATIONS AND RIGHTS OF TERMINATION    28

ARTICLE XX TERM    29

ARTICLE XXI REGULATORY BODIES    29

ARTICLE XXII ARBITRATION    30

ARTICLE XXIII DISPUTES    30

ARTICLE XXIV NOTICES AND PAYMENTS    31

ARTICLE XXV ASSIGNMENT    32

ARTICLE XXVI MISCELLANEOUS    33

ARTICLE XXVII LIQUID NOMINATIONS AND IMBALANCES    34

EXHIBITS

EXHIBIT A    Contract Area; Dedicated Leases; Dedicated Wells

EXHIBIT B    Gathering System Delivery Point(s); Plant Delivery Point(s)

EXHIBIT C    Residue Gas Delivery Point(s); Plant Products Delivery Point(s)

EXHIBIT D    Excluded Shut-In Wells

EXHIBIT E    Mash Unit

EXHIBIT F    Take-in-Kind Procedures

EXHIBIT G    Compression Adjustments

Gas Gathering and Processing Agreement

THIS GAS GATHERING AND PROCESSING AGREEMENT (this "Agreement") is made and entered into as of the Effective Date by and among COWTOWN PIPELINE PARTNERS L.P., a Texas limited partnership ("Gatherer"), COWTOWN GAS PROCESSING PARTNERS LP., a Texas limited partnership, ("Processor"), and BlueStone Natural Resources II, LLC, a Delaware limited liability company, ("Producer"). Gatherer, Processor and Producer are sometimes referred to herein, individually, as a "Party" and, collectively, as the "Parties".

WITNESSETH, THAT:

WHEREAS, Producer has acquired the Dedicated Properties (as defined below) from Quicksilver Resources Inc. (“QRI”) and is in the business of producing gas and owns gas production from one or more wells on the lands within the Contract Area and desires for Gatherer to gather such gas and Processer to process such gas for recovery and delivery of Plant Products and redeliver Gas Residue to Producer or Producer’s nominee;

WHEREAS, Gatherer is in the business of providing natural gas gathering services along its Gathering System and desires to receive, gather and deliver such gas to Processor at the Plant, subject to the terms and conditions herein;

WHEREAS, Processor is in the business of providing natural gas processing services at the Plant and desires to receive such gas for recovery and delivery of Plant Products and redelivery of Residue Gas to Producer or Producer’s nominee, subject to the terms and conditions herein; and

NOW, THEREFORE, in consideration of the representations, warranties and mutual premises and benefits contained herein and for other good and valuable consideration, the adequacy, receipt and sufficiency of which are hereby acknowledged, Gatherer, Processor and Producer agree as follows:

ARTICLE IDEFINITIONS

1.1.
For the purpose of this Agreement, the following terms and expressions used herein are defined as follows:

a.
"Affiliate" shall mean, as to the person specified, any person controlling, controlled by or under common control with such specified person. The concept of control, controlling or controlled as used in the aforesaid context means the possession, directly or indirectly, of the power to direct or cause the direction of the management and policies of another, whether through the ownership of voting securities, by contract or otherwise. Gatherer and Processor acknowledge and agree that Producer’s majority owner is a private equity sponsor that owns and controls a number of other portfolio companies engaged in the oil and gas business and that none of such other portfolio companies shall be considered an "Affiliate" under this Agreement if neither Producer nor any personnel of Producer directly or indirectly direct or cause the direction of the management and policies of that company. Producer acknowledges and agrees that Gatherer and Processor are controlled by First Reserve Corporation, which owns and controls a number of other portfolio companies engaged in the oil and gas business and none of such other portfolio companies shall be considered an "Affiliate" under this Agreement if neither Gatherer or Processor nor any personnel of Gatherer or Processor directly or indirectly direct or cause the direction of the management and policies of that company.

b.
"Asset Purchase Agreement" shall mean that certain Asset Purchase Agreement by and among QRI, Cowtown Gas Processing L.P. and Cowtown Pipeline L.P. and Producer, dated January 22, 2016.

c.
"Base Fee" shall have the meaning set forth in Section 12.1 of this Agreement.

d.
"Btu" shall mean one British thermal unit, which is the quantity of heat required to raise one pound avoirdupois of pure water from 58.5 degrees Fahrenheit to 59.5 degrees Fahrenheit at a constant pressure of 14.73 pounds per square inch absolute.

e.
"Component" shall mean those hydrocarbon and non-hydrocarbon molecular constituents, which are definable by industry standards and procedures. Such Components as used in this Agreement shall be:

N2 - Nitrogen

CO₂ - Carbon Dioxide

H2S - Hydrogen Sulfide

C1 - Methane

C2 -Ethane

C3 - Propane

iC4 - Iso-butane

nC4 - Normal Butane

iC5 - Iso-pentane

nC5 - Normal Pentane

C6+ - Hexanes and Heavier Compounds

f.
"Contract Area" shall mean that area as described or outlined on Exhibit A which is attached hereto and made a part hereof for all purposes, but specifically excludes Producer’s and/or its Affiliates’ leasehold interests owned immediately prior to the Effective Date within the Contract Area but not listed on Exhibit A.

g.
"CPI Adjustment" shall mean that percentage equal to the percentage increase between:

(i)
the seasonally unadjusted Consumer Price Index for Urban Wage Earners and Clerical Workers (all items), U.S. city Average (1982-84=100), as published by the U.S. Department of Labor, Bureau of Labor Statistics ("CPI-W") for the month of December of the second year prior to the Escalation Date; and

(ii)
the seasonally unadjusted CPI-W for the month of December immediately preceding the Escalation Date.

h.
"Day" shall mean a period of twenty-four (24) consecutive hours beginning and ending at seven o'clock a.m. Central Time.

i.
"Dedicated Properties" shall mean (i) Producer’s and/or its Affiliates’ leasehold interests as of the Effective Date within the Contract Area in and to those certain oil, gas and/or mineral leases listed on Exhibit A, and (ii) Producer’s and/or its Affiliates’ interests within the Contract Area in and to any new oil, gas and/or mineral lease acquired by Producer or its Affiliates after the Effective Date, provided that any wells on lands covered by such lease or lands pooled therewith and within the Contract Area are connected to the Gathering System pursuant to Section 4.4.

j.
“Downstream Transporter” shall mean those pipeline operators receiving Residue Gas and Plant Products for the account of Producer.

k.
“Effective Date” shall have the meaning set forth in Section 1(c) of the Letter Agreement.

l.
"Escalation Date" shall mean January 1, 2018 and each January 1st thereafter.

m.
"Facilities" shall mean the Plant and the Gathering System.

n.
"Field Drip" shall mean all liquid hydrocarbons that are recovered from Subject Gas on the Gathering System by means of mechanical separation downstream of one or more Gathering System Delivery Point(s) and redelivered from the field separators owned by Gatherer to storage tanks owned and controlled by Producer. Gatherer, at its sole discretion, may remove or otherwise bypass such separators at any time and from time to time during the term of this Agreement.

o.
"Gas" shall mean natural gas which is owned or controlled by Producer or its successors and assigns producible from wells drilled on Dedicated Properties or lands pooled therewith within the Contract Area, including casinghead gas produced with crude oil, gas from gas wells produced in association with crude oil (associated gas), and gas from condensate wells (non-associated gas), and shall include any inerts or impurities contained therein.

p.
"Gathering Drip" shall mean all liquid hydrocarbons recovered from Subject Gas by means of mechanical separation from the Gathering System in the field and at the inlet of the plant. This will include any liquids that are recovered from the continuous mechanical separation of gas and liquids either from separators that are part of the Gathering System and at the plant inlet as well as any liquid hydrocarbons obtained from time to time associated with pipeline pigging operations on the Gathering System.

q.
"Gathering System" shall mean, but shall in no way be limited to, the gas gathering pipelines, fuel gas pipelines, dehydration facilities, compression facilities, junctions, heaters, meters, separators (including field separators downstream of Gathering System Delivery Points), electric power lines, communications cables, roads, and other related facilities and equipment, including all easements located thereon, from the inlet flange of the pipeline metering facility installed up to the inlet flange of the separation facilities installed upstream of the Plant inlet meter, necessary to gather and transport gas from the Gathering System Delivery Point(s) to the Plant Delivery Point(s) and shall include any expansion of the Gathering System as provided in Section 4.4.

r.
"Gathering System Delivery Point(s)" shall mean the inlet flange of Gatherer's owned or operated metering facilities located at or near each of Producer's wells located within the Contract Area or such other point as may be mutually agreed upon by the Parties. The Gathering System Delivery Point(s) are listed on Exhibit B to this Agreement which is attached hereto and made a part hereof for all purposes and which may be amended from time to time to reflect the addition or deletion of a Gathering System Delivery Point.

s.
“Letter Agreement” means that certain letter agreement executed by the Parties contemporaneously with this Agreement.

t.
"Liquefiable Hydrocarbons" shall mean ethane, propane, iso-butanes, normal butanes, iso-pentanes, normal pentanes, hexanes and heavier hydrocarbons, and incidental methane, or any mixtures thereof, which can be recovered or extracted in the Gathering System or the Plant and sold as Plant Products.

u.
“Lift Gas” shall mean the Gas, reserved by Producer under Section 3.2, used by Producer for gas lift operations in the Mash Unit.

v.
“Mash Unit” shall mean those wells more particularly described on Exhibit E.

w.
“Mash Unit Lateral” shall mean that portion of the Gathering System on which the Lift Gas is delivered from Gatherer’s and/or Processor’s Facilities to the Mash Unit Redelivery Point.

x.
“Mash Unit Redelivery Point” shall mean the point of interconnect between the Mash Unit Lateral and Producer’s facilities for receipt of the Lift Gas located at the Mash Unit, whereby Gatherer redelivers the Lift Gas to Producer, such points being also set forth on Exhibit E attached hereto.

y.
"MCF" shall mean 1,000 standard cubic feet of gas.

z.
"MMBtu" shall mean 1,000,000 Btu's.

aa.
"MMCF" shall mean 1,000,000 standard cubic feet of gas.

bb.
"MMCFD" shall mean 1,000,000 standard cubic feet of gas per day.

cc.
"Month," "billing month," "period," and "accounting period" shall mean the period beginning at seven o'clock a.m. on the first day of a calendar month and ending at seven o'clock a.m. on the first day of the next succeeding calendar month.

dd.
"Net Ethane Sales Price" means Producer’s sales proceeds for Ethane Plant Product net of all fees and costs incurred or charged from the Plant Products Delivery Points to the points of sale divided by total Ethane gallons sold.

ee.
"Net Residue Sales Price" means Producer’s sales proceeds for all Residue Gas net of all fees and costs incurred or charged from the Residue Gas Delivery Point(s) to the points of sale divided by the total Residue Gas MMBtus sold.

ff.
"Plant" shall mean, but shall in no way be limited to, all tanks, machinery, equipment, buildings, structures, fixtures, appliances, pipe, valves, fittings, and materials of any nature or kind whatsoever located on the site at which the processing, compression, and recompression facilities of Processor are currently located in Hood County, Texas (generally known as the Cowtown Plant), or any other site where such facilities may later be located, including by way of additions to, expansion or new development of the Plant or such related facilities, which shall include, without limitation, the Corvette Plant; including appropriate storage, compression, metering, shipping, dehydration, and delivery facilities for Plant Products; all easements pertaining to rights-of-way, the site or sites, and the operation of the Plant; and any and all other facilities and appurtenances located, or to be located, on or away from such site or sites deemed by Processor to be necessary for the successful operation of the Plant, including inlet compression, if any, but not including the Residue Gas Delivery Facility.

gg.
"Plant Delivery Point(s)" shall mean the point(s) of interconnect between the Gathering System and the Plant which point(s) are shown on Exhibit B which is attached hereto and made a part hereof for all purposes.

hh.
"Plant Fuel" shall mean the MMBtu's of the Subject Gas consumed at the Plant for fuel which shall include, but shall in no way be limited to, fuel used for the Subject Gas compression, conditioning and treating; recovery, extraction, and removal of Plant Products; and the recompression of the Residue Gas.

ii.
"Plant Products" shall mean all Liquefiable Hydrocarbons recovered, extracted, or otherwise removed from the Subject Gas after the Plant Delivery Point(s), including, but not limited to, plant condensate (sometimes referred to as pentanes plus, heavier than butanes, or natural gasoline), and all commercial non-hydrocarbon substances recovered, extracted, or otherwise removed from the Subject Gas in the Gathering System or the Plant. For the avoidance of doubt, Plant Products shall not include Field Drip but shall include Gathering Drip.

jj.
"Plant Products Delivery Point" shall mean either (a) the point(s) of interconnect between that certain liquids pipeline owned and operated by Gatherer, and the facilities of third party pipeline(s) to which the Plant Products are delivered and which point(s) are shown on Exhibit C which is attached hereto and made a part hereof for all purposes or (b) the truck loading facilities of the Plant.

kk.
"Plant Tailgate" shall mean the point of interconnect between the Plant and the Residue Gas Delivery Facility located at the downstream flange of the block valve which is downstream of the Plant residue meter and emergency shutdown valve.

ll.
"Primary Term" shall have meaning set forth in ARTICLE XX.

mm.
"Process Flare" shall mean any MMBtu's of the Subject Gas dispersed or lost at the Plant as flare which shall include, but shall in no way be limited to, flare dispersed or lost in the compression, conditioning and treating of the Subject Gas; recovery, extraction, and removal of Plant Products; and the recompression of Residue Gas.

nn.
"psia" shall mean pounds per square inch absolute.

oo.
"psig" shall mean pounds per square inch gauge.

pp.
"Residue Gas" shall mean that hydrocarbon and non-hydrocarbon stream of the Subject Gas remaining after the recovery, extraction, and removal of Plant Products, and after reduction for the Subject Gas used for Plant Fuel, Process Flare, and other incidental losses, including line loss.

qq.
"Residue Gas Delivery Facility" shall mean the residue gas pipeline and associated equipment that are located at the Plant Tailgate and are used to deliver the Residue Gas to the Residue Gas Delivery Point(s).

rr.
"Residue Gas Delivery Point(s)" shall mean the point(s) of interconnect between the Residue Gas Delivery Facility and the facilities of third party pipeline(s) to which the Residue Gas is delivered and which point(s) are shown on Exhibit C which is attached hereto and made a part hereof for all purposes.

ss.
“SCF" or "standard cubic foot of gas" shall mean the amount of Gas necessary to fill a cubic foot of space when the Gas is at a pressure of 14.65 pounds per square inch absolute and a temperature of sixty (60) degrees Fahrenheit.

tt.
"Subject Gas" means the Gas other than natural gas owned by Tokyo Gas and subject to the Tokyo Gas Gathering and Processing Agreement.

uu.
"Term" shall have the meaning set forth in ARTICLE XX of this Agreement.

vv.
"Tokyo Gas" shall mean TG Barnett Resources LP, and its successors and assigns.

ww.
“Tokyo Gas Gathering and Processing Agreement” shall mean that certain Sixth Amended and Restated Gas Gathering and Processing Agreement between Quicksilver Resources Inc., Tokyo Gas, Gatherer and Processor dated September 1, 2008, as amended, replaced or assigned.

xx.
"Treating Fee" shall have the meaning set forth in Section 12.4 of this Agreement.

ARTICLE II
DEDICATION & COMMITMENT

2.1.
Subject to the terms and provisions hereof, Producer (a) dedicates the Dedicated Properties to the Gathering System for gathering by Gatherer and to the Plant for processing by Processor and (b) commits to deliver, at the Gathering System Delivery Point(s), the total volume of Subject Gas, from wells now or hereafter drilled on the lands covered by the Dedicated Properties or lands pooled therewith, excluding Subject Gas reserved or utilized by Producer or its successors and assigns in accordance with the terms of ARTICLE III. Any transfer by Producer of its right, title, or interest in the Dedicated Properties or in the Subject Gas owned by Producer, or in an oil and gas lease, fee mineral interest or other agreement, interest or right which creates or gives rise to Producer’s interest in the Subject Gas owned by Producer, to a third party, whether by farmout, contract, or otherwise, shall be subject to this Agreement. In addition, Producer will notify any person to whom Producer transfers all or a portion of its right, title, or interest in or out of the Dedicated Properties or the Subject Gas owned by Producer that such Dedicated Properties, and the Subject Gas owned by Producer located under the lands covered by such Dedicated Properties, is dedicated pursuant to the terms of this Agreement to be gathered and processed in the Facilities. Producer will notify Gatherer and Processor of any such transfer within ten (10) days of the effective date of such transfer. Failure of Producer to comply with the foregoing shall not affect Gatherer’s or Processor’s rights herein or the dedication being binding on successors or assignees.

2.2.
Gas shall be delivered to the Gathering System Delivery Point(s) after mechanical separation by Producer for the removal of free water and free liquid hydrocarbons, but shall not otherwise be processed by Producer for the removal of Liquefiable Hydrocarbons.

2.3.
Gatherer agrees that subject to the provisions hereof, (i) it will take and, subject to Section 6.1, gather the Subject Gas from the Gathering System Delivery Point(s) and will cause the Subject Gas to be delivered to the Plant Delivery Point(s) for processing and (ii) provided that Producer provides the required fuel, it will redeliver the Lift Gas from its Facilities to the Mash Unit Redelivery Point; provided, however, either Processor or Gatherer may interrupt such deliveries, but only to the extent the same would cause operational issues and/or constraints at the Facilities.

2.4.
Processor agrees that subject to the provisions hereof, including without limitation Section 6.1, it will receive the Subject Gas at the Plant Delivery Point(s) and will cause the Subject Gas to be processed in the Plant for the recovery and delivery of Plant Products. Unless Producer makes an election for Processor to operate the Plant in ethane recovery mode, Processor shall operate the Plant in ethane rejection mode. Producer shall have a monthly election for Processor to operate the Plant in rejection or recover mode by giving Processor written notice no less than ten (10) business Days before the first Day of the calendar Month for which the election is being made. Producer’s election shall be effective until replaced by a new election. When operating the Plant for ethane rejection, Processor will use commercially reasonable efforts to extract the minimum ethane recovery rate that is achievable from time to time, and, when operating the Plant for ethane recovery, Processor will use commercially reasonable efforts to extract the maximum ethane recovery rate that is achievable from time to time, in each case subject to then-existing operating conditions at the Plant, the Gathering System, and Downstream Transporters and in neither case will processor be required to meet any deemed minimum or maximum level of Plant ethane recovery rate.

2.5.
Producer hereby represents and warrants to Gatherer, the following: (i) Exhibit A contains true, accurate, and complete descriptions of all oil, gas and/or mineral leases within the Contract Area acquired from QRI pursuant to the terms to Asset Purchase Agreement and owned by Producer or its Affiliates as of the Effective Date, which are dedicated and committed to the Gathering System as of the Effective Date; and (ii) Producer or its Affiliates have the right to dedicate and commit such oil, gas and/or minerals leases to the Gathering System. To the extent that Producer did acquire from QRI pursuant to the Asset Purchase Agreement oil, gas and/or mineral leases within the Contract Area which have been omitted from Exhibit A, such oil, gas and/or mineral leases shall be deemed to be included on Exhibit A and the Parties shall promptly amend Exhibit A to add such omitted oil, gas and/or mineral leases. Such amendments to Exhibit A shall be Gatherer’s sole and exclusive remedy for Producer’s breach of any representation or warranty in this Section 2.5.

2.6.
Processor agrees to deliver at the Residue Gas Delivery Point(s) to Producer or Producer's nominee the Residue Gas as determined under the provisions of Section 10.2.

2.7.
To the extent Producer acquires any additional leasehold interests within the Contract Area that are subject to an existing services contract with Gatherer or Processor, such interests shall remain subject to such contract until the expiration or termination of such contract unless Producer, Gatherer, and Processor mutually agree to a release under the terms of such contract and dedicate and commit the interests to this Agreement. To the extent Producer acquires any additional leasehold interests within the Contract Area that are subject to an existing dedication, such interests shall not be subject to this Agreement for so long as the prior dedication remains in effect without Producer exercising any extension rights or entering into an agreement to extend the duration of the prior dedication.

2.8.
Either Party may record a mutually agreeable form of memorandum of this Agreement in the official public records of the counties located within the Contract Area.

ARTICLE III
RESERVATIONS OF PARTIES

3.1.
Producer reserves all liquid hydrocarbons, oil, or condensate removed by Producer by means of mechanical gas-liquid separators (including heater-treaters), drips, and/or lines from the Gas prior to delivery to Gatherer at the Gathering System Delivery Points. If mechanical cooling is performed by Producer to meet the temperature specifications of this Agreement, Producer shall not reduce the temperature of the Gas below sixty (60) degrees Fahrenheit.

3.2.
Producer reserves all Gas that may be required for cycling, repressuring, pressure maintenance, and gas lift operations with respect to gas reservoirs on the premises committed hereunder; provided, however, that the Subject Gas used in such operations shall be subject to the terms of this Agreement (to the extent that such Subject Gas can be economically saved) and delivered to Gatherer and Processor following the cessation of such operations.

3.3.
Producer reserves that amount of Gas which is required for above ground development and operation within the Contract Area.

3.4.
Producer expressly reserves the right to deliver or furnish to Producer's lessor Gas as required to satisfy the terms of Producer's oil and gas leases.

ARTICLE IV
GATHERING SYSTEM DELIVERY POINT(S),
PLANT DELIVERY POINT(S) AND PRESSURE

4.1.
Producer, at its own expense, shall construct, equip, maintain, and operate all facilities (including, but not limited to, all necessary separation, dehydration, and/or compression equipment) necessary to deliver the Gas to Gatherer at the Gathering System Delivery Point(s) at such pressure as is required and sufficient to enter the Gathering System, but not to exceed the lesser of one thousand two-hundred (1,200) psig or the maximum allowed operating pressure specified by Gatherer.

4.2.
Whether to facilitate the movement of the Gas on the Gathering System or for other reasons, Gatherer shall provide compression for the Gas on the Gathering System, and Producer will provide its pro rata share of fuel required for operating such compression equipment and any related facilities. Commencing on the first of the Month that is one hundred and twenty (120) Days after Producer brings online previously shut-in wells pursuant to Section 19.4(a), the Base Fee shall be adjusted up or down, based upon the Monthly average pressure of the Gas at the Gathering System Delivery Points in accordance with the table set forth on Exhibit G.

4.3.
Gatherer, at Producer's expense, shall install, construct and equip all meters and facilities necessary to measure the Subject Gas at the Gathering System Delivery Point(s). Gatherer, at its own expense, shall maintain and operate such meters throughout the term of this Agreement.

4.4.
If Producer acquires additional mineral interests or oil, gas and/or mineral leases within the Contract Area, Producer shall notify Gatherer with any proposed reasonable supporting documentation (including the location of any existing or proposed well(s)) sufficient for Gatherer to evaluate whether building an expansion of the Gathering System to any existing or proposed well on such new mineral or leasehold interests would be economic pursuant to the fee structure set forth in this Agreement. Gatherer, in its sole and absolute discretion, may decline to construct any Gathering System expansion to connect the Gathering System to any wells located on lands covered by such new mineral or leasehold interests or lands pooled therewith. Within sixty (60) Days after receiving notice (or, if later, reasonable supporting documentation) from Producer, Gatherer may either elect to construct the expansion pursuant to the fee structure set forth in this Agreement or propose an alternative fee structure that Gatherer deems economic. If Gatherer elects to construct the expansion pursuant to the fee structure set forth in this Agreement, Gatherer shall complete such expansion and be ready to accept Subject Gas as follows: (a) for an expansion requiring two (2) or fewer miles to connect the well(s) to the Gathering System, no later than one hundred and twenty (120) days; and (b) for all other expansions, as soon as reasonably practicable using diligent efforts, but in no event longer than one (1) year; provided that the foregoing time periods in (a) and (b) shall be extended day-for-day for the duration of any events of force majeure affecting Gatherer’s performance, after receiving notice (or, if later, reasonable supporting documentation) from Producer. In the event such expansion is not completed and accepting Subject Gas within such time period, the affected new mineral or leasehold interest and land pooled therewith (but excluding any Dedicated Properties already connected to Gatherer’s System) shall, at Producer’s election by written notice to Gatherer delivered within five (5) days following such period of time, no longer be Dedicated Properties hereunder or subject to this Agreement in any manner whatsoever. If Gatherer proposes an alternative fee structure, then Producer may elect in its sole and absolute discretion to either (i) construct the connection to the Gathering System at Producer’s sole cost and expense, (ii) amend this Agreement to provide for the alternative fee structure proposed by Gatherer, in which case Gatherer shall construct the connection; or (iii) not connect such leasehold interests the Gathering System. If Gatherer elects to not connect, then the new mineral or leasehold interest and land pooled therewith (but excluding any Dedicated Properties already connected to Gatherer’s System) shall no longer be Dedicated Properties hereunder or subject to this Agreement in any manner whatsoever. If Producer elects to build the connection itself, such Gathering System expansion must meet all of Gatherer's specifications, and Gatherer will be responsible for the meter station and connection to the existing Gathering System. Gatherer may, at its election, but only within two years (2) of the initial delivery of production from the connection to the Gathering System, acquire the ownership of the connecting facilities installed by Producer by reimbursing Producer for the actual cost with no allowance for inflation or depreciation. In such event, Producer agrees to execute all assignments or contracts deemed reasonably necessary to accomplish the transfer to Gatherer of title to the Gathering System expansion, including rights-of-way and easements, on an “as is, where is” basis and with other terms and conditions customary for the purchase and sale of midstream assets within the Contract Area.

4.5.
Gatherer hereby agrees to deliver the Gas to Processor at the Plant Delivery Point(s) at the prevailing Gathering System pressure. Processor hereby agrees to utilize the Plant’s inlet compression to compress such gas to a pressure sufficient to enter the Plant up to 1,050 psig.

ARTICLE V
REGULATION OF PRODUCTION

5.1.
It is understood and agreed by the Parties that in order for Gatherer and Processor to maintain maximum efficiency in the Facilities, and in order to prevent flaring and/or bypassing of the Subject Gas, it will be necessary to maintain a uniform rate of flow of the Subject Gas to the Facilities from all sources during each twenty-four (24) hour period. Therefore, Producer agrees that it will cooperate with Gatherer and Processor in regulating the flow rate of the Subject Gas and in establishing a producing schedule to deliver on a commercially reasonable basis the Subject Gas at a uniform and continuous flow rate. In the event that Gatherer enters into an operational balancing agreement with a third party pipeline, Producer hereby agrees to be bound by the terms set forth therein.

ARTICLE VI
QUANTITY

6.1.
The Parties acknowledge and agree that natural gas (including Gas) which is owned by Tokyo Gas is subject to the Tokyo Gas Gathering and Processing Agreement and may be delivered to Gatherer by Producer pursuant to a joint operating agreement between Producer and Tokyo Gas.

6.2.
Subject to Gathering System and Plant capacity, Gatherer shall gather and Processor shall process that volume of the Subject Gas legally allowed to be produced from the interest owned or controlled by Producer or its successors and assigns in wells drilled on lands within the Contract Area or lands pooled therewith; provided, after processing, Producer or Producer's nominee will accept the Residue Gas. Processor shall regulate the flow of gas at the Plant in the quantities and at the times desired by Processor to prudently operate the Plant and/or to meet the fluctuating condition of Processor's and Producer's markets. Gatherer or Processor may, from time to time, find it necessary to shut off entirely or restrict the flow of gas to the Gathering System or Plant, respectively, including but not limited to as a result of routine maintenance and other planned outages, capacity constraints (subject to Section 6.6), compliance with laws or regulations, force majeure events (subject to Article XVIII), emergencies, or material adverse operational issues at the Facilities; notwithstanding anything herein to the contrary, in such event, neither Gatherer nor Processor shall be liable to Producer for the resulting effect thereof. Gatherer and Processor shall provide Producer prior notice of any shut down due to routine maintenance and other planned outages and shall prudently work to minimize the amount of such downtime.

6.3.
Producer shall nominate to Gatherer in writing, not less than three (3) business Days prior to the first day of each Month during the term of the Agreement, the daily quantity of the Subject Gas and the natural gas owned by Tokyo Gas (expressed in MCF's and MMBtu's) that Producer shall deliver to Gatherer at the Gathering System Delivery Point(s) for gathering during such Month, either pursuant to this Agreement or the Tokyo Gas Gathering and Processing Agreement. The Parties acknowledge and agree that natural gas owned by Tokyo Gas and delivered to Gatherer by Producer shall, pursuant to Section 6.1, be gathered and processed by Gatherer and Processor pursuant to the Tokyo Gas Gathering and Processing Agreement. Producer shall also nominate to Processor in writing, not less than three (3) business Days prior to the first day of each Month during the term of the Agreement, the daily quantity of Residue Gas and residue gas owned by another producer but controlled by Producer (expressed in MCF's and MMBtu's) that Producer or Producer's nominee shall receive at the Residue Gas Delivery Point(s) following processing at the Plant.

6.4.
Gatherer, Processor, and Producer shall designate a dispatcher(s) who shall be continuously on call for nomination purposes, and shall notify each other in writing of such dispatcher(s) and their telephone number(s).

6.5.
Producer's dispatcher shall notify Gatherer's and Processor's dispatchers in advance of any anticipated decrease in delivery rate below the daily nominated quantity. Producer's dispatcher must obtain the prior written approval from Gatherer's and Processor's dispatchers for any delivery rate in excess of the daily quantity rate. Gatherer's and Processor's dispatcher shall notify Producer's dispatcher of any anticipated inability to receive the Subject Gas at a delivery rate less than (a) the daily nominated quantity rate; or (b) a previously orally authorized delivery rate in excess of the daily nominated quantity rate.

6.6.
If insufficient Plant or pipeline capacity exists to process all the Subject Gas, the Plant processing capacity will be prorated for all gas dedicated to the Plant, without undue discrimination; provided, however, during the time period during which Processor is unable to process all of the Subject Gas, Producer may dispose of the unprocessed Subject Gas as it sees fit and if such inability to process all of the Subject Gas continues for a period of sixty (60) consecutive days, extended day-for-day for the duration of events of force majeure affecting Processor’s performance, then the Subject Gas produced from the affected well(s) shall, at Producer’s election by written notice to Gatherer and/or Processor thirty (30) days' advance delivered prior to cessation of proration, no longer be Dedicated Properties hereunder or subject to this Agreement in any manner whatsoever.

6.7.
Subject to Producer’s reservation in Section 3.1, Producer agrees that Processor has the exclusive right to process, or cause to be processed, blend, or cause to be blended, the Subject Gas for the extraction of natural gas liquids and other valuable components. Processor shall have the right, but not the obligation, to expand the Plant or build a new gas processing plant at a different location, and in such event, the Subject Gas, or a portion thereof, may be processed by Processor in the expanded Plant or the new gas processing plant in accordance with the terms of this Agreement.

6.8.
Producer, Gatherer and Processor shall conduct semi-annual technical meetings at which Producer shall provide Gatherer with estimated monthly volume forecasts, drilling and development plans for the next twelve (12) months, and discuss other operational matters, and at which Gatherer shall provide Producer Gatherer’s projected maintenance and system outage schedules, Facilities pressures and operating constraints, and system balances for the next twelve (12) months, and discuss other operational matters.

ARTICLE VII
QUALITY

7.1.
Gatherer and Processor shall not be obligated to receive, gather and/or process (as the case may be), the Subject Gas delivered hereunder that fails to meet (i) the quality specifications of any Downstream Transporter at any of the Residue Gas Delivery Point(s) or Plant Products Delivery Point(s), or (ii) the following specifications:

a.
The Subject Gas must be commercial in quality and free from any foreign materials such as dirt, dust, iron particles, crude oil, dark condensate, free water, and other impurities; and substances which may be injurious to pipelines or which may interfere with the gathering, processing, transmission, or commercial utilization of said Subject Gas;

b.
The Subject Gas shall contain no free water or hydrocarbons in liquid form;

c.
The Subject Gas delivered hereunder shall not exceed a temperature of one hundred twenty (120) degrees Fahrenheit at the Gathering System Delivery Point(s), as well as the Plant Delivery Point(s);

d.
The Subject Gas delivered hereunder shall not contain more than:

(i)
One-fourth grain of hydrogen sulfide, or five grains of total sulfur, or one grain mercaptan per one hundred (100) cubic feet;

(ii)
one part per million by volume of oxygen;

(iii)
that percent by volume of carbon dioxide which would result in the failure of the Residue Gas or the Plant Products to meet the specifications of any Downstream Transporter at any of the Delivery Points, but in no event more than two percent by volume;

(iv)
two percent by volume of nitrogen; or

(v)
three percent by volume of a combined total of inerts, including, but not limited to, carbon dioxide and nitrogen Components;

e.
No diluents such as carbon dioxide, air, or nitrogen shall be added to the Subject Gas;

f.
The Subject Gas shall contain no carbon monoxide, halogens, or unsaturated hydrocarbons, and no more than 0.1 parts per million of hydrogen; and

g.
The Subject Gas shall contain no less than 1,100 Btu and 2 GPM ethane and heavier hydrocarbons.

7.2.
In the event of any conflict as between specifications of a Downstream Transporter and those above, the most stringent or restrictive specifications shall be applicable to the Subject Gas proffered under this Agreement. With respect to the “no water” or “hydrocarbons in liquid form” specification, Producer agrees to operate its facilities in a prudent manner so that no water or hydrocarbons in liquid form enters the Gathering System. In the event Gatherer receives liquid water or hydrocarbons from Producer at any Gathering System Delivery Point, in addition to any adjustments to gas measurement that may be necessary to accurately reflect the quantity of the Subject Gas delivered by Producer to Gatherer at such Gathering System Delivery Point, Gatherer shall have the right, if such receipts of liquid water or hydrocarbons have not ceased within seven (7) Days after Gatherer’s written notice to Producer, to cease taking deliveries of the Subject gas at such Gathering System Delivery Point until such time as Producer rectifies the situation. If any of the Subject Gas delivered by Producer hereunder should fail to meet the quality specifications set forth in this ARTICLE VII, Gatherer and Processor may elect to either (i) accept and process such Subject Gas, (ii) accept, but treat and/or condition such Subject Gas prior to gathering or processing at an additional cost, or (iii) refuse to accept such Subject Gas. The acceptance of the Subject Gas not meeting the quality specifications set forth in ARTICLE VII shall not be deemed a waiver of Gatherer's and Processor's right to reject such Subject Gas at any later time, and Gatherer and Processor shall be entitled, at any time and from time to time, to decline to accept proffered deliveries of the Subject Gas not meeting the quality specifications set forth herein.

7.3.
If Gatherer and Processor elect to accept but treat and/or condition the nonconforming Subject Gas prior to gathering and processing, Gatherer and Processor shall advise Producer of such election and associated fees. Producer shall then have a maximum of thirty (30) days to advise Gatherer and Processor if it will treat and/or condition such nonconforming Subject Gas and the cost associated with such treatment. If Producer does not elect to treat and/or condition such non-conforming Subject Gas or fails to make such election within the specified time period, then Gatherer and Processor shall have the right to (a) proceed with gathering and processing such non-conforming Subject Gas and Producer shall pay to Gatherer and Processor all costs associated with such actions or (b) reject and release such non-conforming Subject Gas from the terms of the Agreement. Notwithstanding anything in this Section 7.3 to the contrary, Producer agrees that to the extent nonconforming Subject Gas at a Gathering System Delivery Point is accepted and subsequently treated or conditioned with respect to its CO₂ Component, such treating shall be done for the Treating Fee described and provided in Section 12.4 below.

7.4.
If there is an enactment of, or change in, any law after the Effective Date that, in Gatherer’s or Processor’s reasonable determination, results in a governmental authority requiring Gatherer or Producer to hold or acquire emission allowances or their equivalent related to the carbon dioxide content or emissions or the greenhouse gas content or emissions attributable to Gas and/or the gathering and/or processing of such Gas (collectively, “Producer’s GHG Emissions”), then Gatherer or Processor, as applicable, will notify Producer of such enactment of, or change in, such law. Thereafter, Producer shall use commercially reasonable efforts to provide any required emissions allowances or their equivalents to Gatherer and Processor, as applicable, in a timely manner. If Producer fails to provide such emission allowances or their equivalents and Gatherer or Processor incurs expenses to acquire such allowances or their equivalents in the marketplace, or incurs any out-of-pocket costs or expenses for disposal or treating of carbon dioxide, or otherwise, or if any other additional economic burden is placed on Gatherer or Processor in connection with or related to Producer’s GHG Emissions, including but not limited to any tax, assessment, or other cost or expense (collectively, “Emissions Charges”), such Emissions Charges shall be fully the responsibility of Producer. Should Gatherer or Processor incur any such Emissions Charges, Producer shall reimburse Gatherer or Processor, as applicable, for the same within thirty (30) Days of receipt of an invoice along with reasonable supporting documentation. If carbon dioxide is sold by Gatherer or Processor on behalf of Producer, then the proceeds, net of Emissions Charges, taxes, and costs and expenses of such sale, shall be paid to Producer or deducted from amounts owed by Producer pursuant to this Agreement. Notwithstanding the foregoing, should any such enactment of, or change in, law require Gatherer or Processor to construct new facilities or to modify any part of the Gathering System or the Plant under this Section 7.4, the Parties shall negotiate in good faith and use commercially reasonable efforts to agree on the most cost effective method of constructing or modifying such facilities.

ARTICLE VIII
TESTS

8.1.
Producer, Gatherer and Processor do hereby agree as follows:

a.
Gatherer shall procure or cause to be procured a sample of the Subject Gas at each Gathering System Delivery Point and Plant Delivery Point, respectively, and analyze the samples by chromatographic analysis to determine the Component content (mole percent), specific gravity, the BTU content, and the Plant Product content (expressed in gallons per MCF) thereof.

b.
The individual Plant Products contained in the commingled stream of plant products delivered from the Plant each month shall be determined from a chromatographic analysis of either (a) a spot sample or a sample taken from a continuous sampling device or (b) from an online chromatograph. The results of the chromatographic analysis shall be applied to the commingled stream of plant products to determine the volume of each individual Plant Product delivered from the Plant.

c.
Tests provided for in Subparagraphs (a) and (b) of this Section 8.1 shall be made by Gatherer and Processor using their own equipment or by an independent testing service. Samples will be taken at each Gathering System Delivery Point according to the monthly average daily flow capabilities of such Gathering System Delivery Point as follows: Gathering System Delivery Point(s) that average 5,000 Mcf per day and higher shall be sampled monthly; Gathering System Delivery Points that average between 4,999 Mcf and 1,000 Mcf per day shall be sampled quarterly; and Gathering System Points of Delivery that average below 1,000 Mcf per day shall be tested semi-annually or more often as Gatherer deems necessary. All such tests shall be made in accordance with approved engineering practices. Representatives of Producer shall be entitled to witness such tests, and Producer shall give advance written notice to Gatherer and Processor in the event that it exercises such right.

8.2.
Physical constants required for making calculations hereunder shall be taken from the Gas Processors Association Physical Constants Publication No. 2145-03 (as amended from time to time). Physical constants for the hexanes and heavier hydrocarbons portion of hydrocarbon mixtures shall be assumed to be the same as the physical constants for hexane. The heat content per gallon of each liquid hydrocarbon Component shall be determined by multiplying the cubic feet per gallon of such liquid hydrocarbon Component by the heat content per cubic foot thereof.

ARTICLE IX
MEASUREMENT AND METER TESTING

9.1.
The unit of volume for measurement of Gas delivered hereunder shall be one thousand (1,000) cubic feet of Gas at a base temperature of sixty (60) degrees Fahrenheit and at an absolute pressure of 14.65 psia and saturated with water vapor. All fundamental constants, observations, records, and procedures involved in determining the quantity of the Subject Gas delivered hereunder shall be in accordance with the standards prescribed in Report Nos. 3 and 8, of the American Gas Association, as amended or supplemented from time to time, respectively. It is agreed that for the purpose of measurement and computations hereunder, the atmospheric pressure shall be assumed to be 14.65 psia regardless of the atmospheric pressure at which the Gas is measured and that the Gas obeys the Ideal Gas Laws as to variations of volume with pressure and specific gravity, including the deviation from Boyle's law, shall all be made by Gatherer and Processor in accordance with applicable rules, regulations, and orders. It is also agreed that Gatherer and Processor may apply a uniform correction factor for water vapor if they deem necessary in their sole and absolute discretion.

9.2.
Gatherer shall install, maintain, and operate, or cause to be maintained and operated, a measuring station located at each Gathering System Delivery Point, the Residue Gas Delivery Point(s), the Mash Unit Redelivery Point and the Plant Products Delivery Point. Processor shall install, maintain, and operate a measuring station located downstream of the separation facilities at each Plant Delivery Point. Said measuring station(s) shall be so equipped with orifice meters, recording gauges, or other types of meter or meters of standard make and design commonly acceptable in the industry, and of suitable size and design, as to accomplish the accurate measurement of the Subject Gas delivered hereunder. The changing and integration of the charts (if utilized for measurement purposes hereunder) and calibrating and adjusting of meters shall be done by Gatherer or Processor, as appropriate. Gatherer and Processor shall have the right to utilize electronic gas measuring equipment should they so desire.

9.3.
Processor shall measure or cause to be measured the volume of Plant Products in gallons.

9.4.
Producer may, at its option and expense, install check meters for checking Gatherer's metering equipment at each Gathering System Delivery Point and the Mash Unit Redelivery Point; and the same shall be so installed as not to interfere with the operation of the Facilities.

9.5.
The temperature of the Subject Gas flowing through the meter shall be determined by the continuous use of a recording thermometer or device installed by Gatherer or Processor, as the case may be, so that it will properly record the temperature of the Subject Gas flowing through the meter.

9.6.
The specific gravity of the Subject Gas flowing through the meter shall be determined by methods commonly accepted in the industry. Specific gravities so determined will be used in calculating the Subject Gas deliveries until the next specific gravity test is made.

9.7.
Each Party shall have the right to be present at the time of any installing, reading, sampling, cleaning, changing, repairing, inspecting, testing, calibrating, or adjusting done in connection with the other's measuring equipment used in measuring deliveries hereunder. The records from such measuring equipment shall remain the property of their owner, but upon request, each will submit to the other its records and charts, together with calculations therefrom subject to return within thirty (30) days after receipt thereof. If meters utilizing charts are used to measure the Subject Gas hereunder, then the charts shall be kept on file for a period of two (2) years, or such longer period as may be required by law. In addition, any other measurement data shall also be kept for the same time period. Each Party, during each of the first three production months, and after that at least semi-annually, or more often if necessary, shall calibrate the meters and instruments installed by it or cause the same to be calibrated. Gatherer shall give Producer ten (10) days notice in advance of such tests so that the latter may, at its election, be present in person or by its representative to observe adjustments, if any are made.

9.8.
If the metering equipment is found to be inaccurate by two percent (2%) or more, registration thereof and any payment based upon such registration shall be corrected at the rate of such inaccuracy for any period of inaccuracy which is definitely known or agreed upon, or if not known or agreed upon, then for a period extending back one-half of the time elapsed since the last day of the calibration. Unless conclusively determined that either Gatherer's or Processor's measurement equipment is inaccurate by two percent (2%) or more, Gatherer's or Processor's, as the case may be, measurement shall be deemed to be correct for all purposes hereunder, and no adjustment shall be made to the previous volumes. Following any test, any metering equipment found to be inaccurate to any degree shall be adjusted immediately to measure accurately. If for any reason any meter is out of service or out of repair so that the quantity of the Subject Gas delivered through such meter cannot be ascertained or computed from the readings thereof, the quantity of the Subject Gas so delivered during such period shall be estimated and agreed upon by the Parties hereto upon the basis of the best available data using the first of the following methods which is feasible:

a.

By using the registration of any check measuring equipment of
Producer, if installed and registering accurately;

b.

By correcting the error if the percentage of error is ascertainable by
calibration, test, or mathematical calculation; or

c.

By estimating the quantity of deliveries during preceding periods
under similar conditions when the meter was registering accurately.

9.9.
If Producer shall notify Gatherer, or if Gatherer shall notify Producer, at any time that a special test of any Gathering System Delivery Point or the Mash Unit Redelivery Point meter is desired, the Parties shall cooperate to secure an immediate verification of the accuracy of such meter and joint observation of any adjustments. All tests of Gatherer's measuring equipment at any Gathering System Delivery Point or the Mash Unit Redelivery Point shall be made at Gatherer's expense, except that Producer shall bear the expense of tests made at its request if the inaccuracy found is less than two percent (2%). Expense as used in this Section 9.9 shall be limited to actual out-of-pocket costs of Gatherer as the result of testing and shall not include any costs incurred by Producer as the result of witnessing said testing.

9.10.
If during any month less than 1,000 MCF of Subject Gas is delivered to a Gathering System Delivery Point or the Mash Unit Redelivery Point (except for reasons of force majeure), then Gatherer shall charge a meter fee applicable to any such Gathering System Delivery Point or the Mash Unit Redelivery Point, as applicable, equal (***). Such fee shall be deducted from the compensation otherwise due Producer under this Agreement; or, at Gatherer's election, Producer may be invoiced for such amount payable thirty (30) days after receipt.

9.11.
The Parties hereto recognize and acknowledge that technological advances may occur over the term of this Agreement which may render certain measurement devices obsolete, or less accurate, or less efficient than that which may be available. In such event, Gatherer or Processor may, with Producer's approval, substitute or utilize such available measurement equipment in lieu of any measurement equipment described above in this ARTICLE IX.

9.12.
If for any reason the Subject Gas is delivered to Gatherer at a Gathering System Delivery Point with pulsations that affect the accuracy of the measurement, Producer shall be responsible for installing necessary pulsation dampeners, or other devices, to eliminate or reduce the pulsations to a reasonably acceptable level determined by Gatherer.

ARTICLE X
ALLOCATION PROCEDURE

10.1.
With regard to the allocation of Plant Products, for each accounting period, the actual Plant Products will be allocated to each Gathering System Delivery Point in the ratio of the Theoretical Plant Product Content of each Gathering System Delivery Point over the sum of the Theoretical Plant Product Content for all Gathering System Delivery Points. The Component amount will be determined by analysis at the Plant Products Delivery Point.

The "Theoretical Plant Product Content of each Gathering System Delivery Point" shall equal the product of the Gathering System Delivery Point's share of plant inlet MCF multiplied by the GPM (Gallons per MCF) as determined by the chromatograph analysis of a sample of the Gathering System Delivery Point.

10.2.
With regard to the allocation of Field Drip, all drip recovered from time to time will be redelivered from the field separators owned by Gatherer to storage tanks owned and controlled by Producer.

10.3.
With regard to the allocation of the Gathering Drip, for each accounting period, actual Gathering Drip will be allocated to each Gathering System Delivery Point in the ratio of the product of the Gathering System Delivery Point’s share of plant inlet MCF multiplied by the GPM (Gallons per MCF) of hexanes and heavier hydrocarbons as determined by the chromatograph analysis of a sample of the Gathering System Delivery Point.

10.4.
With regard to the allocation of Residue Gas, for each accounting period, the actual metered residue gas at each Residue Gas Delivery Point shall be allocated to each Gathering System Delivery Point in the ratio of the calculated Theoretical Residue Remaining for the Gathering System Delivery Point over the sum of Calculated Theoretical Residue Remaining for all Gathering System Delivery Points.

The "Calculated Theoretical Residue Remaining" shall equal each Gathering System Delivery Point's share of plant inlet volume MCF\MMBtu, minus each Gathering System Delivery Point Plant Product shrinkage (product shrinkage factors based on GPA 2145-03 bulletin), minus the allocated Plant Fuel.

ARTICLE XI
DISPOSITION OF PRODUCER'S PORTION OF PLANT PRODUCTS

Producer shall take its Plant Products in-kind at the Plant Products Delivery Points upon the terms and subject to the conditions set forth in the Take-in-Kind Procedures attached hereto as Exhibit F.

ARTICLE XII
GATHERING AND PROCESSING FEES

12.1.
Producer shall pay to Gatherer (***) per MMBtu of Subject Gas gathered pursuant to this Agreement as measured at the Gathering System Delivery Point(s) (the "Base Fee").

12.2.
Producer shall each month pay to Processor an additional rate equal to (***) of the published (***) Index, on all volumes measured at the Gathering System Delivery Point(s) (on an MMBtu basis) plus an amount equal to (***) of Plant Products volumes multiplied by the average (***) Index for each gallon of Plant Products for the month divided by the Subject Gas gathered for such month pursuant to this Agreement as measured at the Gathering System Delivery Point(s) (on an MMBtu basis).

12.3.
Producer shall pay to Gatherer (***) per MMBtu of Lift Gas redelivered to Producer at the Mash Unit Redelivery Point (the "Lift Gas Fee").

12.4.
In the event Subject Gas requires treating to meet the quality requirements set forth in Section 7.1(d)(iii) and Gatherer and Processor treat such Subject Gas pursuant to Section 7.3, Producer shall pay to Processor a treating fee (the "Treating Fee") of (***) per MMBtu of the Subject Gas metered at the applicable Gathering System Delivery Point where such Subject Gas was delivered.

12.5.
On each Escalation Date, the Base Fee, the Lift Gas Fee and the Treating Fee will increase by a percentage equal to the CPI Adjustment.

ARTICLE XIII
DISPOSITION OF PRODUCER'S PORTION OF RESIDUE GAS

Processor will deliver the Residue Gas to the Residue Gas Delivery Point(s). Processor agrees to deliver Producer's Residue Gas at a pressure sufficient to enter the third party natural gas pipeline(s), but in no event shall Processor be obligated to deliver Residue Gas at a pressure which exceeds the Plant discharge pressure of one thousand and sixty (1,060) psig. Producer will separately contract with a third party regarding the transportation and sale of their Residue Gas.

ARTICLE XIV
ACCOUNTING. PAYMENTS AND CREDIT ASSURANCES

14.1.
Producer shall furnish to Gatherer and Processor on or before the first day of each month a report or statement disclosing information necessary to enable Gatherer and Processor to determine the percentage of gas delivered at each Gathering System Delivery Point that is Subject Gas owned by Producer and the percentage of Gas delivered at each Gathering System Delivery Point that is owned by any other working interest owner for which Producer delivered Gas to the Gathering System (and each such working interest owner’s respective percentage of such gas) related to the preceding month. Gatherer and Processor shall furnish to Producer on or before the twenty-fifth (25th) day of each month a report or statement disclosing information necessary to enable Producer to make reasonable and accurate statistical and accounting entries upon its books concerning all phases of this Agreement related to the preceding month, including an allocation statement of Residue Gas delivered for Producer's account to its Residue Gas purchaser and the amounts due Gatherer and Processor for the services provided hereunder. Producer shall remit the amounts due Gatherer and Processor with respect to the Subject Gas within thirty (30) days after the receipt of Gatherer's and Processor's statement. PRODUCER SHALL INDEMNIFY AND HOLD GATHERER AND PROCESSOR HARMLESS FROM ANY ALL CHARGES, PENALTIES, COSTS AND EXPENSES OF WHATEVER KIND OR NATURE ARISING FROM PRODUCER'S FAILURE TO PAY SUCH PAYMENTS, INCLUDING COSTS AND EXPENSES OF ANY LITIGATION AND REASONABLE ATTORNEYS' FEES ASSOCIATED THEREWITH. Unpaid amounts due with respect to the Subject Gas shall accrue interest at the lesser of a rate equal to (***), until the balance is paid in full.

14.2.
Each Party shall have the right during reasonable hours to examine books, records, charts, and original test data of another Party to the extent necessary to verify the accuracy of any statement, charge, credit, computation, test, or delivery made pursuant to any provision hereof. If any such examination reveals any inaccuracy in any such statement, charge, credit, computation, test, or delivery, the necessary adjustment shall be promptly made without interest or penalty. No Party will have any right to recoup or recover prior overpayments or under payments that result from error that occur in spite of good faith performance if the amounts involved do not exceed one thousand dollars ($1,000.00).

14.3.
[Reserved]

14.4.
Producer shall be responsible for the payment of all royalties due on the Gas. PRODUCER SHALL INDEMNIFY AND HOLD GATHERER AND PROCESSOR HARMLESS FROM ANY AND ALL CLAIMS, ACTIONS, CAUSEStokyo OF ACTION, DAMAGES, LIABILITY, OR OBLIGATIONS ARISING OUT OF OR IN ANY WAY RELATED TO THE PAYMENT OF THE LESSOR'S ROYALTY OR ANY OTHER BURDEN OR ENCUMBRANCE AFFECTING THE GAS.

14.5.
Notwithstanding any change in ownership of Producer's properties, Gatherer and Processor shall never be required to make payments or to give notices required under the provisions of this Agreement to more than one party.

14.6.
Either Party may, at its option, recoup any sums (or portions thereof) due and owing by the other Party by netting out of such Party’s payments to the other Party all or part of the sums due and owed by the other Party under this Agreement. When a Party elects to net out certain indebtedness under the Agreement of the other Party, such Party shall promptly send to the other Party a description of (a) the source or nature of the indebtedness of the other Party that has been recouped in whole or in part by such Party in the above-referenced manner, including the dollar amount of such recoupment, and (b) the indebtedness of the Party that has been reduced through such recoupment.

14.7.
All accounting records and documents directly related to this Agreement prepared by any Party hereto shall be retained for a period of not less than two (2) years following the end of the calendar year of their origination. The Parties further agree that all matters relating to the accounting hereunder for any calendar year shall be considered correct and not subject to further audit or legal challenge after two years following the end of the calendar year.

14.8.
    Credit Assurances.

a.
Producer will be deemed creditworthy: (i) during a period in which Producer does not have long-term secured debt securities rated by S&P and Moody’s, then if according to the most recent of (y) Producer’s audited annual financial statements, or (z) Producer’s quarterly financial statements, (A) its current ratio (dividing current assets (which shall include available borrowings under its credit facility and undrawn equity committed by its equity holders) by current liabilities) is (***) or higher and (B) its leverage ratio as determined using the methodology required by its bank group is at least (***) below its then-current bank group covenant but in no event greater than (***); or (ii) otherwise, if its long-term unsecured debt securities are rated at least BB- by Standard & Poor's Corporation ("S&P") and at least Ba3 by Moody's Investor Service ("Moody's"); provided, however, that if the Producer's rating is at BB- or Ba3 and the short-term or long-term outlook is negative, Gatherer and Processor may require further analysis. Producer shall provide its most recent audited financial statements on the Effective Date and, in the event Producer does not have long-term unsecured debt securities rated by S&P and Moody’s, then Producer must also provide Gatherer audited annual financial statements on an annual basis and unaudited quarterly financial statements on a quarterly basis.

b.
If Producer does not meet the criteria described above, then Producer may request that Gatherer and Processor evaluate its creditworthiness based upon the level of service requested relative to the Producer's current and future ability to meet its obligations. Further, if Producer's creditworthiness does not meet any of the foregoing criteria, Producer will be considered creditworthy if Producer maintains and delivers to Gatherer and Processor an irrevocable guaranty of payment in form acceptable to Gatherer and Processor, or an irrevocable letter of credit from a financial institution rated at least A- by S&P or at least A3 by Moody's, in a form acceptable to Gatherer and Processor, in either case of the guaranty or the letter of credit in an amount satisfactory to Gatherer and Processor, which will be equal to the total amounts invoiced to Producer by Gatherer and Processor in the immediately preceding two (2) Months. The obligation to maintain such credit assurance shall extend until such time as Producer is deemed creditworthy as defined herein. Producer shall provide the guaranty or the letter of credit within twenty (20) days of written notice by Gatherer and Processor that such financial assurance is required.

c.
The creditworthiness requirements set forth in this Section 14.8 shall apply to any permitted assignment (in whole or in part), and to any permitted permanent release, as applicable, of this Agreement. Gatherer and Processor shall apply consistent evaluation practices to all similarly situated producers to determine the Producer's financial ability to perform the payment obligations due to Gatherer and Processor.

ARTICLE XV
WARRANTY

15.1.
Producer warrants the title to all the Subject Gas owned by Producer and authority to act on behalf of all Subject Gas and all Components thereof which shall be delivered by Producer to Gatherer and Processor hereunder, the right to enter into this Agreement with reference to Subject Gas, and that Subject Gas owned by Producer is free from all liens and adverse claims; AND AGREES, IF NOTIFIED THEREOF BY GATHERER OR PROCESSOR, TO INDEMNIFY, DEFEND AND HOLD GATHERER AND PROCESSOR HARMLESS FROM AND AGAINST ANY AND ALL SUITS, ACTIONS, LOSSES, DEBTS, ACCOUNTS, DAMAGES, COSTS, AND EXPENSES ARISING FROM OR OUT OF ANY ADVERSE CLAIM AS TO PRODUCER'S TITLE, INCLUDING, BUT NOT LIMITED TO, ANY ADVERSE CLAIM BROUGHT BY OR THROUGH A MINERAL INTEREST OR ROYALTY OWNER, TO OR AGAINST THE SUBJECT GAS OWNED BY PRODUCER AND AGAINST THE PLANT PRODUCTS DERIVED THEREFROM. Producer agrees to make settlement for all royalties, overriding royalty interests, and/or production payments due and payable on the Subject Gas delivered to Gatherer and Processor hereunder, the Plant Products extracted and saved therefrom, and the sale and disposition of the Residue Gas thereof, all in accordance with the terms of the leases from which the Subject Gas processed hereunder is produced, applicable instruments of title, and all amendments thereto.

15.2.
Producer also represents and warrants that it has full authority to receive payment for the sum of all of the Subject Gas delivered hereunder.

ARTICLE XVI
TAXES

16.1.
Producer shall pay or cause to be paid all production, severance and ad valorem taxes, assessments, and other charges levied or assessed against the Gas delivered by Producer hereunder, and against Producer's portion of the Plant Products, against Producer's Residue Gas, and against the sale thereof, and all taxes and statutory charges levied or assessed against any of Producer's properties, facilities, or operations.

16.2.
Processor shall pay all taxes and statutory charges levied or assessed against the Plant and operations concerning such plant.

16.3.
Gatherer shall pay all taxes and statutory charges levied or assessed against the Gathering System and operations concerning such system.

ARTICLE XVII
INDEMNITY

17.1.
As between the Parties, and as to liability, if any, accruing to a Party hereto, or to any third party, Producer shall be solely liable for and in control and possession of the Gas deliverable hereunder until the Gas is delivered to Gatherer at the Gathering System Delivery Point(s). Gatherer shall be solely liable for and in control and possession of the Gas deliverable hereunder until the Gas is delivered to Processor at the Plant Delivery Point(s). Processor shall be solely liable for and in control and possession of the Gas and the Plant Products until Processor has delivered Residue Gas to Producer at the Residue Gas Delivery Point(s) whereupon Producer shall again be in control and possession thereof and bear the risk of loss of the Residue Gas. If Lift Gas is redelivered to Producer as provided herein, then, in that event, Gatherer shall be solely liable for and in control and possession of such Lift Gas from the time such Lift Gas exits Gatherer’s or Processor’s Facilities until redelivered to Producer at the Mash Unit Redelivery Point, whereupon Producer shall again be in control and possession and bear the risk of loss of such Lift Gas.

17.2.
PRODUCER SHALL BE AFFORDED ACCESS TO GATHERER'S AND PROCESSOR'S PROPERTY AND THE FACILITIES TO THE EXTENT NECESSARY TO CARRY OUT ITS RIGHTS AND OBLIGATIONS UNDER THIS AGREEMENT, AND PRODUCER SHALL FULLY OBSERVE AND COMPLY WITH ALL OF GATHERER'S AND PROCESSOR'S SAFETY PRACTICES AND PROCEDURES WHILE ON THE PREMISES. PRODUCER HEREBY AGREES TO INDEMNIFY, HOLD HARMLESS, PROTECT, DEFEND, AND DISCHARGE GATHERER AND PROCESSOR AND THEIR AFFILIATED COMPANIES, PARTNERS, SUCCESSORS, ASSIGNS, OFFICERS, DIRECTORS, MANAGERS, SHAREHOLDERS, MEMBERS, EMPLOYEES AND AGENTS FOR, FROM AND AGAINST ANY AND ALL JUDGMENTS, EXECUTIONS, CAUSES OF ACTION, DEMANDS, RIGHTS, SUITS, DEBTS AND SUMS OF MONEY, ACCOUNTINGS, DUES, PENALTIES, FINES, CLAIMS (INCLUDING, WITHOUT LIMITATION, CLAIMS FOR CONTRIBUTION), LIABILITIES, LOSSES, COSTS, DAMAGES AND EXPENSES (INCLUDING COURT COSTS, REASONABLE COSTS OF INVESTIGATION, DEFENSE AND ATTORNEY'S FEES) FOR THE INJURY TO OR DEATH OF ANY PERSON (INCLUDING, WITHOUT LIMITATION, EACH OF PRODUCER'S, GATHERER'S AND PROCESSOR'S EMPLOYEES, AGENTS AND CONTRACTORS) OR PROPERTY DAMAGE OF ANY NATURE, KIND OR DESCRIPTION OR ANY OTHER CLAIM OF ANY NATURE, KIND OR DESCRIPTION BROUGHT BY ANY PERSON OR ENTITY, WHETHER LEGAL OR EQUITABLE, WHICH ARISES OUT OF, RESULTS FROM OR IS IN ANY WAY RELATED TO (i) PRODUCER'S OWNERSHIP AND CONTROL OF (a) THE GAS PRIOR TO THE TIME THAT THE GAS PASSES THROUGH THE GATHERING SYSTEM DELIVERY POINT(S) AND AFTER THE RESIDUE GAS PASSES THROUGH THE RESIDUE GAS DELIVERY POINT(S), (b) THE PLANT PRODUCTS AFTER THE PLANT PRODUCTS PASS THROUGH THE PLANT PRODUCTS DELIVERY POINT AND (c) THE LIFT GAS AFTER THE LIFT GAS HAS PASSED THROUGH THE MASH UNIT REDELIVERY POINT AND PRIOR TO THE TIME THAT GAS, INCLUDING SUCH LIFT GAS, PASSES THROUGH THE GATHERING SYSTEM DELIVERY POINT, (ii) PRODUCER'S OWNERSHIP AND OPERATION OF THE WELLS LOCATED WITHIN THE CONTRACT AREA AND ANY FACILITIES OR EQUIPMENT INSTALLED OR MAINTAINED BY PRODUCER UPSTREAM OF THE GATHERING SYSTEM DELIVERY POINT, REGARDLESS OF WHETHER SUCH WAS REQUIRED BY THE TERMS OF THIS AGREEMENT, (iii) THE PERFORMANCE OF ANY OBLIGATIONS, RIGHTS OR DUTIES BY PRODUCER HEREUNDER, (iv) PRODUCER'S BREACH OF THIS AGREEMENT, OR (v) ANY VIOLATION OF THE LAW BY PRODUCER OR ITS AFFILIATES OR REPRESENTATIVES, REGARDLESS OF EITHER GATHERER'S OR PROCESSOR'S SOLE, CONCURRENT OR COMPARATIVE NEGLIGENCE.

17.3.
GATHERER HEREBY AGREES TO INDEMNIFY, HOLD HARMLESS, PROTECT, DEFEND AND DISCHARGE PROCESSOR AND PRODUCER AND THEIR AFFILIATED COMPANIES, PARTNERS, SUCCESSORS, ASSIGNS, OFFICERS, DIRECTORS, MANAGERS, SHAREHOLDERS, MEMBERS, EMPLOYEES AND AGENTS, FOR, FROM AND AGAINST ANY AND ALL JUDGMENTS, EXECUTIONS, CAUSES OF ACTION, DEMANDS, RIGHTS, SUITS, DEBTS AND SUMS OF MONEY, ACCOUNTINGS, DUES, PENALTIES, FINES, CLAIMS (INCLUDING, WITHOUT LIMITATION, CLAIMS FOR CONTRIBUTION), LIABILITIES, LOSSES, COSTS, DAMAGES AND EXPENSES (INCLUDING COURT COSTS, REASONABLE COSTS OR INVESTIGATION, DEFENSE AND ATTORNEY'S FEES) OF ANY NATURE, KIND OR DESCRIPTION BROUGHT BY ANY PERSON OR ENTITY, WHETHER LEGAL OR EQUITABLE, WHICH ARISE OUT OF, RESULT FROM OR ARE IN ANY WAY RELATED TO (i) GATHERER'S CONTROL OF (a) THE GAS AFTER THE GAS PASSES THROUGH THE GATHERING SYSTEM DELIVERY POINT(S) AND PRIOR TO THE TIME THAT THE GAS PASSES THROUGH THE PLANT DELIVERY POINT(S) and (b) THE LIFT GAS FROM THE TIME SUCH LIFT GAS EXITS GATHERER’S OR PROCESSOR’S FACILITIES UNTIL SUCH LIFT GAS PASSES THROUGH THE MASH UNIT REDELIVERY POINT, (ii) GATHERER'S OWNERSHIP AND OPERATION OF THE GATHERING SYSTEM, (iii) THE SERVICES PROVIDED BY GATHERER PURSUANT TO THIS AGREEMENT, (iv) GATHERER'S BREACH OF THIS AGREEMENT, OR (v) ANY VIOLATION OF THE LAW BY GATHERER OR ITS AFFILIATES OR REPRESENTATIVES, REGARDLESS OF PRODUCER'S OR PROCESSOR'S SOLE, CONCURRENT OR COMPARATIVE NEGLIGENCE.

17.4.
PROCESSOR HEREBY AGREES TO INDEMNIFY, HOLD HARMLESS, PROTECT, DEFEND AND DISCHARGE GATHERER AND PRODUCER AND THEIR AFFILIATED COMPANIES, PARTNERS, SUCCESSORS, ASSIGNS, OFFICERS, DIRECTORS, MANAGERS, SHAREHOLDERS, MEMBERS, EMPLOYEES AND AGENTS, FOR, FROM AND AGAINST ANY AND ALL JUDGMENTS, EXECUTIONS, CAUSES OF ACTION, DEMANDS, RIGHTS, SUITS, DEBTS AND SUMS OF MONEY, ACCOUNTINGS, DUES, PENALTIES, FINES, CLAIMS (INCLUDING, WITHOUT LIMITATION, CLAIMS FOR CONTRIBUTION), LIABILITIES, LOSSES, COSTS, DAMAGES AND EXPENSES (INCLUDING COURT COSTS, REASONABLE COSTS OR INVESTIGATION, DEFENSE AND ATTORNEY'S FEES) OF ANY NATURE, KIND OR DESCRIPTION BROUGHT BY ANY PERSON OR ENTITY, WHETHER LEGAL OR EQUITABLE, WHICH ARISE OUT OF, RESULT FROM OR ARE IN ANY WAY RELATED TO (i) PROCESSOR'S CONTROL OF (a) THE GAS AFTER THE GAS PASSES THROUGH THE PLANT DELIVERY POINT(S) AND PRIOR TO THE TIME THAT THE RESIDUE GAS PASSES THROUGH THE RESIDUE GAS DELIVERY POINT(S) AND (b) THE PLANT PRODUCTS UNTIL THE PLANT PRODUCTS PASS THROUGH THE PLANT PRODUCTS DELIVERY POINT, (ii) PROCESSOR'S OWNERSHIP AND OPERATION OF THE PLANT, (iii) THE SERVICES PROVIDED BY PROCESSOR PURSUANT TO THIS AGREEMENT, (iv) PROCESSOR'S BREACH OF THIS AGREEMENT, OR (v) ANY VIOLATION OF THE LAW BY PROCESSOR OR ITS AFFILIATES OR REPRESENTATIVES, REGARDLESS OF GATHERER'S OR PRODUCER'S SOLE, CONCURRENT OR COMPARATIVE NEGLIGENCE. THE INDEMNIFICATION RIGHTS HEREIN SHALL BE CUMULATIVE OF, AND IN ADDITION TO, ANY AND ALL OTHER RIGHTS, REMEDIES OR RECOURSE OF THE PARTIES AND SHALL SURVIVE ANY EXPIRATION OR TERMINATION OF THIS AGREEMENT. TO THE EXTENT AND ONLY TO THE EXTENT THE FOREGOING INDEMNIFICATION RIGHTS ARE BY LAW, EITHER INAPPLICABLE OR NOT ENFORCEABLE, PRODUCER, GATHERER AND PROCESSOR SHALL EACH BE RESPONSIBLE FOR THE RESULTS OF ITS OWN ACTIONS AND FOR THE ACTIONS OF THOSE PERSONS AND ENTITIES OVER WHICH IT EXERCISES CONTROL.

17.5.
NOTWITHSTANDING ANYTHING CONTAINED IN THIS ARTICLE XVII OR ELSEWHERE IN THIS AGREEMENT TO THE CONTRARY, NO PARTY SHALL BE LIABLE FOR ANY PUNITIVE, EXEMPLARY, CONSEQUENTIAL, INCIDENTAL, SPECIAL, OR INDIRECT DAMAGES, LOST PROFITS, OR OTHER BUSINESS INTERRUPTION DAMAGES, IN TORT OR CONTRACT, IN CONNECTION WITH OR OTHERWISE ARISING OUT OF THIS AGREEMENT, EXCEPT TO THE EXTENT SUCH DAMAGES HAVE BEEN AWARDED TO A THIRD PARTY WHO IS NOT AN AFFILIATE OF A PARTY AND ARE SUBJECT TO ALLOCATION BETWEEN OR AMONG THE PARTIES PURSUANT TO ANY TERMS OF THIS AGREEMENT.

ARTICLE XVIII
FORCE MAJEURE

In the event any Party is rendered unable, either wholly or in part, by force majeure to carry out its obligations under this Agreement, other than the obligation to make payments due hereunder, it is agreed that on such Party giving notice and full particulars of such inability by telephone and in writing to the other Parties as soon as possible after the occurrence of the cause relied on, then the obligations of the Party giving such notice, so far as they are affected by such force majeure, shall be suspended during the continuance of any inability so caused, but for no longer period, and such cause shall, as far as possible, be remedied with all reasonable dispatch by the Party claiming the force majeure. The term "force majeure" as employed herein shall mean any act or event which wholly or partially prevents or delays the performance of obligations arising under this Agreement if such act or event is not reasonably within the control of and not caused by the fault or negligence of the Party claiming force majeure and which by the exercise of due diligence such Party is unable to prevent or overcome, including, without limitation, by the following enumeration: acts of God; strikes; lockouts; or other industrial disturbances; acts of the public enemy; wars; blockades; insurrections; riots; epidemics; landslides; lightning; earthquakes; fires; storms; floods; washouts; arrests and restraints of governments and people; civil disturbances; explosion, breakage, or accidents to machinery, plant facilities, or lines of pipe; the necessity for making repairs to or alterations of machinery, plant facilities, or lines of pipe; freezing of wells or lines of pipe; partial or entire failure of wells; and the inability of either Producer, Gatherer or Processor to acquire, or the delays on the part of either Producer, Gatherer or Processor in acquiring, at reasonable cost and after the exercise of reasonable diligence: (a) any servitude, rights-of-way grants, permits, or licenses; (b) any materials or supplies for the construction or maintenance of facilities; and (c) any permits or permissions from any governmental agency if such are required. It is understood and agreed that the settlement of strikes or lockouts shall be entirely within the discretion of the Party having the difficulty and that the above requirements that any force majeure shall be remedied with all reasonable dispatch shall not require the settlement of strikes or lockouts by acceding to the demands of the opposing party when such course is inadvisable in the sole discretion of the Party having the difficulty. Notwithstanding anything contained herein to the contrary, in the event that either Gatherer or Processor is unable to carry out its obligations under this Agreement due to a force majeure, then during the time period of such force majeure, Producer may dispose of the Subject Gas as it sees fit.

ARTICLE I
UNPROFITABLE OPERATIONS AND RIGHTS OF TERMINATION

1.2.
If, in the reasonable opinion of Gatherer, the gathering of the Subject Gas from any well or wells, or any Gathering System Delivery Point, under this Agreement, is or becomes uneconomical due to its volume, government regulations, or any cause other than force majeure, Gatherer shall not be obligated to gather or may cease gathering the Subject Gas therefrom so long as such condition exists. Gatherer agrees that in its determination of uneconomical gathering, the same criteria shall be used for the Subject Gas as for all other gas being gathered through the Gathering System. In the event that Gatherer refuses to gather the Subject Gas, Producer may dispose of the Subject Gas not gathered as it sees fit; provided that Gatherer at any time thereafter shall have the right to gather all of the Subject Gas refused, if refused for reason or reasons resulting from an act of Producer or lack of action on the part of Producer, conditioned upon Gatherer giving Producer at least two (2) months' notice of its election so to do. Notwithstanding anything contained herein to the contrary, in the event that Gatherer refuses to gather the Subject Gas for a period of sixty (60) consecutive days causing Producer's well(s) to be shut-in, Producer shall have the option, exercised solely at its discretion, to terminate the Agreement in its entirety insofar and only insofar as it pertains to the Subject Gas produced from the affected well(s) by providing to Gatherer a thirty (30) days' advance written notice of such termination.

1.3.
If, in the reasonable opinion of Processor, the processing of the Subject Gas from any well or wells, or any Gathering System Delivery Point, under this Agreement, is or becomes uneconomical due to its volume, Plant Product content, government regulations, or any cause other than force majeure, Processor shall not be obligated to process or may cease processing the Subject Gas therefrom so long as such condition exists. Processor agrees that in its determination of uneconomical processing, the same criteria shall be used for the Subject Gas as for all other gas being processed through the Plant. In the event that Processor refuses to process the Subject Gas, Producer may dispose of the Subject Gas not processed as it sees fit; provided that Processor at any time thereafter shall have the right to process all of the Subject Gas refused, if refused for reason or reasons resulting from an act of Producer or lack of action on the part of Producer, conditioned upon Processor giving Producer at least two (2) months' notice of its election so to do. Notwithstanding anything contained herein to the contrary, in the event that Processor refuses to process the Subject Gas for a period of sixty (60) consecutive days, Producer shall have the option, exercised solely at its discretion, to terminate this Agreement insofar as it pertains to the Subject Gas produced from the affected well(s) by providing to Processor a thirty (30) days' advance written notice of such termination.

1.4.
In the event Processor should at any time hereafter elect to permanently discontinue the operation of the Plant, Gatherer, Processor and Producer shall each have the option, exercised solely at its discretion, of terminating this Agreement in its entirety upon one hundred twenty (120) days advance written notice of such termination notice to the other Parties.

1.5.
Nothing herein shall be construed to require Producer to drill any well or to continue to operate any well which a prudent operator would not in like circumstances drill or continue to operate. Notwithstanding the foregoing, (a) Producer intends to produce the maximum volumes possible and commits to bring all wells currently shut in for economic purposes, other than those set forth on Exhibit D, online as soon as practicable, but in no event later than July 1, 2016 and (b) Producer agrees that it will not shut-in or choke back wells for economic purposes during the calendar years of 2016 through the end of 2018 unless the well reaches the end of its useful life or safety, technical or mechanical reasons necessitate shutting-in or choking back the well.

1.6.
It is agreed that neither Gatherer nor Processor shall be obligated to expand the Facilities in order to provide capacity hereunder.

ARTICLE II
TERM

This Agreement shall be effective from the Effective Date and, subject to the other provisions hereof, shall continue in full force and effect until the tenth anniversary of the date Producer first delivers Gas to the Gathering System Delivery Point(s) pursuant to the terms of this Agreement (the "Primary Term") and shall be automatically renewed for one (1) year periods thereafter unless on or before one hundred eighty (180) days prior to the expiration of the Primary Term or the expiration of a one (1) year renewal period a Party hereto provides written notice of termination (the Primary Term and each renewal term shall collectively be referred to as the "Term"). For the avoidance of doubt, this Agreement shall become effective subject to and simultaneously with the "Closing" as such term is defined under the Asset Purchase Agreement.

ARTICLE III
REGULATORY BODIES

This Agreement and the provisions hereof shall be subject to all valid applicable federal, state, and local laws, order, rules, and regulations. Producer, Gatherer and Processor have entered into this Agreement with the understanding, and in reliance on the fact, that this Agreement and/or performance of this Agreement are not and will not be subject to the jurisdiction or regulation of the Federal Energy Regulatory Commission ("FERC"). If this Agreement and/or performance of this Agreement becomes subject to such jurisdiction and/or regulation, this Agreement shall automatically terminate unless Producer, Gatherer and Processor agree, in writing, within thirty (30) days of the effective date of the attachment of any such jurisdiction and/or regulation, that this Agreement shall continue after such effective date.

ARTICLE IV
ARBITRATION

Any controversy between the Parties arising under ARTICLE X of this Agreement and not resolved by agreement shall be determined by a board of arbitration upon notice of submission given either by Processor, Gatherer or Producer, which request shall also name one arbitrator. The Parties receiving such notice shall, within ten (10) days thereafter, by notice to the others, jointly name the second arbitrator, or failing so to do, the Party giving notice of submission shall name the second. The two arbitrators so appointed shall name the third, or failing so to do within ten (10) days, then upon the written application of any Party, such third arbitrator may be appointed by the American Arbitration Association. The arbitrators selected to act hereunder shall be qualified by education, experience, and training to pass upon the particular question in dispute. The jurisdiction of the arbitrators will be limited to the single issue referred to arbitration, and the arbitration shall be conducted pursuant to the guidelines set forth by the American Arbitration Association; provided, however, that should there be any conflict between the guidelines and the procedures set forth in this Agreement, the terms of this Agreement shall control. Within fifteen (15) days following selection of the third arbitrator, each Party shall furnish the arbitrators in writing its position regarding the issue being arbitrated. The arbitrators may, if they deem necessary, convene a hearing regarding the issue being arbitrated. The arbitrators shall render their decision in writing within thirty (30) days after the appointment of the third arbitrator or the conclusion of the hearing, if one is held. If within said period a decision is not rendered by the arbitrators, new arbitrators may be named and shall act hereunder at the election of any of Processor, Gatherer or Producer in like manner as if none has been previously named. The arbitrators' decision shall be final and binding upon the Parties as to the issue submitted and the Parties will abide by and comply with such decision. The expenses of arbitration shall be borne equally by the Parties, except that each Party shall bear the compensation and expenses of its counsel, witnesses, and employees.

ARTICLE V
DISPUTES

5.2.
Subject to the terms as set forth in ARTICLE XXII of this Agreement, should a dispute arise between the Parties, the Parties shall promptly seek to resolve any such dispute by negotiations among the senior executives of the Parties who have the authority to settle such dispute ("Senior Executives") prior to the initiation of any lawsuit or arbitration in accordance with Article XXII. The Senior Executives shall meet at a mutually acceptable time and place within fifteen (15) days and thereafter as often as they reasonably deem necessary to exchange relevant information and to attempt to resolve the dispute. All negotiations and communications pursuant to this ARTICLE XXIII shall be treated and maintained by the Parties as confidential information and shall be treated as compromise and settlement negotiations for purposes of the federal and state Rules of Evidence. If the matter has not been resolved within thirty (30) days after the initial meeting of the Senior Executives, or such longer period as may be mutually agreed upon, any Party may initiate a lawsuit or arbitration in accordance with Article XXII.

5.3.
THIS AGREEMENT, AND ALL QUESTIONS RELATING TO ITS VALIDITY, INTERPRETATION, PERFORMANCE AND ENFORCEMENT (INCLUDING, WITHOUT LIMITATION, PROVISIONS CONCERNING LIMITATIONS OF ACTIONS) SHALL BE GOVERNED BY AND CONSTRUED IN ACCORDANCE WITH THE LAWS OF THE STATE OF TEXAS, NOTWITHSTANDING ANY CONFLICT-OF-LAWS DOCTRINES OF SUCH STATE OR OTHER JURISDICTION TO THE CONTRARY. ALL MATTERS LITIGATED BY OR BETWEEN THE PARTIES THAT INVOLVE THIS AGREEMENT, THE RELATIONSHIP OF THE PARTIES, OR ANY RELATED DOCUMENTS OR MATTERS HEREUNDER SHALL BE BROUGHT ONLY IN HOUSTON, HARRIS COUNTY, TEXAS.

5.4.
IN ANY SUIT FILED BY A PARTY HERETO TO RESOLVE A DISPUTE ARISING UNDER THIS AGREEMENT OR RELATED TO THE SERVICES PROVIDED HEREUNDER, EACH PARTY HEREBY COVENANTS AND AGREES TO TAKE ALL STEPS NECESSARY TO WAIVE A TRIAL BY JURY.

ARTICLE VI
NOTICES AND PAYMENTS

Any notice, request, demand, statement, or bill provided for in this Agreement shall be in writing and delivered by hand, mail, or facsimile. All such written communications shall be effective upon receipt by the other party at the address of the parties hereto as follow:

Producer

Statements:        BlueStone Natural Resources II, LLC

2100 South Utica

Tulsa, OK 74114

Attn: John Redmond

Email: jredmond@bluestone-nr.com

Payments:        BlueStone Natural Resources II, LLC

2100 South Utica

Tulsa, OK 74114

Attn: John Redmond

Email: jredmond@bluestone-nr.com

Contractual:        BlueStone Natural Resources II, LLC

2100 South Utica

Tulsa, OK 74114

Attn: John Redmond

Email: jredmond@bluestone-nr.com

Gatherer

Statements:        Cowtown Pipeline Partners L.P.

1200 Summit Avenue, Suite 320

Fort Worth, Texas 76102

Attn: Revenue Accounting

Payments:        Cowtown Pipeline Partners L.P.

1200 Summit Avenue, Suite 320

Fort Worth, Texas 76102

Attn: Accounting

Contractual:        Cowtown Pipeline Partners L.P.

700 Louisiana, Suite 2550

Houston, Texas 77002

Attn: VP of Commercial

Email: Darrel.hagerman@crestwoodlp.com

Processor

Statements:        Cowtown Pipeline Partners L.P.

1200 Summit Avenue, Suite 320

Fort Worth, Texas 76102

Attn: Revenue Accounting

Payments:        Cowtown Pipeline Partners L.P.

1200 Summit Avenue, Suite 320

Fort Worth, Texas 76102

Attn: Accounting

Contractual:        Cowtown Pipeline Partners L.P.

700 Louisiana, Suite 2550

Houston, Texas 77002

Attn: VP of Commercial

Email: Darrel.hagerman@crestwoodlp.com

Any of the Parties may designate a further or different address by giving written notice to the other Parties.

ARTICLE VII
ASSIGNMENT

This Agreement (and a Party's rights and obligations hereunder) is assignable in whole or in part. This Agreement shall be binding upon and inure to the benefit of the heirs, executors, administrators, successors, and assigns of the respective Parties hereto; provided that no transfer of or succession to the interest of any Party hereunder, either wholly or partially, shall affect or bind the other Parties until it shall have been furnished with the original instrument or with the proper proof that the claimant is legally entitled to such interest.

ARTICLE VIII
MISCELLANEOUS

8.3.
No waiver by any Party of any one or more defaults in the performance of any provision of this Agreement shall operate or be construed as a waiver of any default or future defaults, whether of a like or different character.

8.4.
This Agreement contains the entire agreement between the Parties and there are no oral promises, agreements, or warranties affecting it. This Agreement may be amended or modified from time to time only by the written agreement of all the Parties hereto.

8.5.
The provisions of this Agreement are enforceable by the Parties hereto. Nothing in this Agreement, express or implied, is intended to confer upon any person other than the Parties hereto and their respective successors and assigns, any rights, benefits or obligations hereunder.

8.6.
The descriptive headings of the provisions of these general provisions are formulated and used for convenience only and shall not be deemed to affect the meaning or construction of any such provisions.

8.7.
This Agreement supersedes and replaces any other contract(s) or agreements(s) which may exist between the Parties covering the gathering and processing of the Gas dedicated hereunder; provided the Parties agree that a separate gathering agreement may be executed in substitution of this Agreement to provide for the gathering by Gatherer of gas produced from some portion of the dedicated Contract Area but which is deemed "dry" and not otherwise desirable or acceptable for processing at the Facilities.

8.8.
Nothing in this Agreement is intended to create a partnership or joint venture under state law or to render the Parties hereto jointly and severally liable to any third party. Each of the Parties elects to be excluded from the provisions of Subchapter K, Chapter 1 of Subtitle A, of the Internal Revenue Code of 1986 pursuant to the provisions of Article 761 (a) of such code and from any similar provisions of state law. Processor shall timely file such evidence of this election as may be required under applicable law.

8.9.
Should any section, paragraph, subparagraph, or other portion of this Agreement be found invalid as a matter of law in a duly authorized court, or by a duly authorized government agency, then only that portion of the Agreement shall be invalid. The remainder of the Agreement which shall not have been found invalid shall remain in full force and effect.

8.10.
This Agreement was prepared jointly by the Parties hereunder and not by any Party to the exclusion of the other.

8.11.
Producer recognizes and acknowledges Gatherer's and Processor's proprietary interest in this Agreement, and Producer agrees not to divulge any of the contents hereof to any other person, firm, corporation, or other entity. Producer agrees to be responsible for enforcing the confidentiality of this Agreement and agrees to take such action as necessary to prevent any disclosure by any of its agents or employees.

8.12.
The Parties warrant and represent that no promise, agreement, representation, inducement, or condition which is not herein expressed has been made to either Party by the other, or any agent or representative of either Party to the other, in executing this Agreement.  The Parties further warrant and represent they are not relying upon, and expressly disclaim, any such promise, agreement, representation, inducement, or condition which is not herein expressed in executing this Agreement. The Parties represents and warrant they are relying solely upon their own judgment in entering this Agreement.

8.13.
This Agreement is being executed contemporaneously with the Parties’ Letter Agreement. The Parties represent, warrant, and agree this Agreement and the Letter Agreement collectively comprise one transaction.

ARTICLE IX
LIQUID NOMINATIONS AND IMBALANCES

9.13.
Plant Products Delivery Point(s) Nominations. No later than 12:00 PM, four (4) business days prior to the beginning of each Month, Processor shall notify Producer of the volumes of Plant Products per day that Processor anticipates will be made available for delivery to Producer at the Plant Products Delivery Point(s). No later than 12:00 PM, two (2) business days prior to the start of such Month, Producer shall notify Processor of the Plant Products Delivery Point(s) where Plant Products are to be delivered by Processor and the specific amount of barrels associated therewith. At any time during the term hereof, Producer may adjust its nominations prospectively for the remainder of such Month by providing Processor notice prior to the nomination deadline of the applicable pipeline at the Plant Products Delivery Point(s) for making such changes.

9.14.
Because of dispatching and other causes outside of Processor's reasonable control, imbalances may occur between the Plant Products delivered at the Plant Products Delivery Point(s) for Producer’s account and the Plant Products allocated to Producer as determined in Article X of the Agreement. Processor and Producer shall both use commercially reasonable efforts to manage daily receipts and deliveries so that any imbalances shall be kept as near to zero as practicable. Any imbalances described above shall be resolved in the following manner:

a.
At the same time that Processor provides Producer a statement pursuant to Section 14.1, Processor shall submit to Producer a statement reflecting the (“Liquid Volume Variance”) for the previous Month which shall include the following information: (x) a comparison of (A) the volume of each Plant Product delivered for Producer’s account to the Plant Products Delivery Point(s), to (B) Producer’s allocated Plant Products as determined in Article X of the Agreement, (y) the value, using the pricing in Section 27.2(b) below, of the volume differences determined in such comparison, and (z) such other information and detail as may be mutually agreeable to the Parties. If there are amounts owed by each party pursuant to the Liquid Volume Variance calculation, then Processor shall net such amounts and reflect on the statement the net payment owed by the party with the greater payment obligation. In addition, Processor shall net such amount against the amount owed pursuant to Section 14.1 and reflect on the statement the net payment amount owed by the party with the greater payment obligation, and any payment owed shall be due as provided in Section 14.1, but paid as provided above.

b.
The value to be used for each Plant Product volume imbalance for the production Month shall be the Oil Price Information Service (OPIS) average monthly prices, using purity ethane, NON-TET propane, normal butane, ISO-butane, and natural gasoline, as applicable, less a "Transportation Fee" and a “Fractionation Fee”. For purposes of this Section 27.2(b), the Transportation Fee shall be (***) and the Fractionation Fee shall be the higher of (A) (***) or (B) (***). The Transportation Fee and the fixed portion of the Fractionation Fee shall be adjusted each January during the term hereof, commencing January 11 2015 using the most recent "F.E.R.C. Oil Pipeline Index - Multiplier to Use" as published online by the Federal Energy Regulatory Commission. Gatherer and Processor will provide Producer notice of yearly escalation prices.

9.15.
In the event Producer, Gatherer, or Processor reasonably determines that the prices used in either the Transportation Fee or the Fractionation Fee above in Section 27.2(b) are no longer representative of current market prices, then such Party shall notify the other Parties in writing and propose a new price it reasonably believes to reflect current market value and the effective date of implementing said new price. Upon receipt of said proposal, the receiving Parties shall have 10 days to accept or reject the proposal or deliver a counter proposal to the proposing Party. If the receiving Parties reject the proposal or the proposing Party rejects the receiving Parties' counter proposal within 10 days from the receipt thereof, then the proposing Party may invoke the dispute resolution procedures set forth in Article XXIII to resolve such matter; provided, however, in no event shall the arbitrator(s) establish and set a price for the Fractionation Fee that would be less than (***); provided, further, no Party may invoke this price renegotiation mechanism more than once per any 12 month period. For purposes of this Section 27.3, if the receiving Party fails to reject the proposed price in the proposal within its respective 10 day deadline or if the proposing Party fails to reject the proposed price in the counter proposal from the receiving Parties within its respective 10 day deadline, then such failure shall be deemed acceptance by such Party of the applicable fee.

(SIGNATURE PAGE FOLLOWS)

IN WITNESS WHEREOF, the Parties hereto have executed this Agreement in several originals to be effective as of the Effective Date.

PRODUCER

BlueStone Natural Resources II LLC, a Delaware limited liability company

By:_ /s/ John Redwood                

Name: John Redmond    

Title: President/Chief Executive Officer    

GATHERER

Cowtown Pipeline Partners L.P., a Texas limited partnership

By: Crestwood Gas Services Operating GP LLC, its general partner

By:/s/ J. Heath Deneke______________

Name: J. Heath Deneke

Title: Chief Operating Officer and President, Pipeline Services Group

PROCESSOR

Cowtown Gas Processing Partners L.P., a Texas limited partnership

By: Crestwood Gas Services Operating GP LLC, its general partner

By:/s/ J. Heath Deneke______________

Name: J. Heath Deneke

Title: Chief Operating Officer and President, Pipeline Services Group

EXHIBIT A TO THE

GAS GATHERING AND PROCESSING AGREEMENT

[COWTOWN GAS FACILITIES]

CONTRACT AREA; DEDICATED LEASES & WELLS

This Exhibit A is attached to the Gas Gathering and Processing Agreement (the "Agreement") dated effective April 1, 2016 by and among BlueStone Natural Resources II, LLC, Cowtown Pipeline Partners L.P., and Cowtown Gas Processing Partners L.P. and made a part thereof for all purposes. All defined terms used herein shall have the same meaning as set forth in the Agreement.

Contract Area

Bosque County, Texas

Erath County, Texas

Hood County, Texas

Johnson County, Texas

Parker County, Texas

Somervell County, Texas

Tarrant County, Texas

With regard to Tarrant County, Gas that does not satisfy the quality specifications in Section 7.1(g) of this Agreement shall be dedicated to the Gas Gathering Agreement for the Alliance Area of even date between Producer and Cowtown Pipeline Partners L.P.

Leases & Mineral Interests

See attached sheets.

ST	County	File ID	Lessor	Lease Dated	Recorded County	Vol/Book	Page	Instrument No.
TX	BOSQUE	TX0350014.00	DONALD BEATY WIRZ	8/2/2001	BOSQUE	489	712	03716-01
TX	BOSQUE	TX0350015.01	RONALD CURTIS WIRZ ET UX	8/8/2001	BOSQUE	494	670	04698-01
TX	BOSQUE	TX0350017.01	FRIOU SUSAN ZIMMERMAN IND.	8/9/2001	BOSQUE	489	721	03719-01
TX	BOSQUE	TX0350017.02	KIESCHNICK ANN ZIMMERMAN	6/25/2001	BOSQUE	487	559	003310-01
TX	BOSQUE	TX0350017.03	NEMETH LISA ZIMMERMAN	6/25/2001	BOSQUE	487	568	003313-01
TX	BOSQUE	TX0350017.04	SCOTT JUDITH C ZIMMERMAN	6/25/2001	BOSQUE	487	537	003303-01
TX	BOSQUE	TX0350017.05	ZIMMERMAN ERIKA I M.D.	6/25/2001	BOSQUE	489	718	03718-01
TX	BOSQUE	TX0350017.06	CONNOR SARA ZIMMERMAN	6/25/2001	BOSQUE	487	562	03311-01
TX	BOSQUE	TX0350017.07	CATHY B RAMSEY ET VIR	6/15/2006	BOSQUE	630	837	2006-00003023
TX	BOSQUE	TX0350017.08	CONSTANCE GOULDING ET VIR	6/15/2006	BOSQUE	630	833	3022
TX	BOSQUE	TX0350284.99	JACK JAY POWELL FAMILY TR	8/23/2005	BOSQUE	604	701	4220-05
TX	BOSQUE AND ERATH	TX1430001.00	CLOVIS D GRAVES	6/14/2001	ERATH	1126	58
TX	BOSQUE AND ERATH	TX1430001.00	CLOVIS D GRAVES	6/14/2001	BOSQUE	626	483
TX	BOSQUE AND SOMERVELL	TX4250103.00	ST TX M-103317	10/7/2003	BOSQUE	550	772	5572-03
TX	BOSQUE AND SOMERVELL	TX4250103.00	ST TX M-103317	10/7/2003	SOMERVELL	119	835	36233
TX	BOSQUE AND ERATH	TX1430001.00	CLOVIS D GRAVES	6/14/2001	ERATH	1126	58
TX	BOSQUE AND ERATH	TX1430001.00	CLOVIS D GRAVES	6/14/2001	BOSQUE	626	483
TX	ERATH	TX1430003.00	JIMMIE L RAMAGE ET AL	4/16/2001	ERATH	13551	11
TX	HOOD	TX2210001.00	O C CHEEK ET UX	2/6/2003	HOOD	1909	55	6757
TX	HOOD	TX2210002.00	JAMES C BRYANT JR	2/6/2003	HOOD	1901	328	5188
TX	HOOD	TX2210003.01	Z BAR LAND & CATTLE CO	3/7/2003	HOOD	1909	58	6758
TX	HOOD	TX2210003.02	SIMONTON RECEIVERSHIP	1/19/2005	HOOD	2070	888	898
TX	HOOD	TX2210003.03	LATTIMORE MATERIALS CO L P	11/30/2003	HOOD	1979	513	1068
TX	HOOD	TX2210003.04	CHARLES LUMMUS ET UX	2/26/2003	HOOD	1909	84	6762
TX	HOOD	TX2210003.04	CHARLES LUMMUS ET UX	2/26/2003
TX	HOOD	TX2210003.04	CHARLES LUMMUS ET UX	2/26/2003
TX	HOOD	TX2210003.04	CHARLES LUMMUS ET UX	2/26/2003
TX	HOOD	TX2210003.05	JON KNOX RHODES ET AL	4/30/2003	HOOD	1928	881	10813
TX	HOOD	TX2210003.13	MEEGHAN G WEIDENMULLER	4/26/2010	HOOD	2545	956	5585
TX	HOOD	TX2210003.14	ANDREW S KEAN	1/9/2012	HOOD			2012-0001163
TX	HOOD	TX2210003.15	MARY KEAN	1/9/2012	HOOD			2012-0001745
TX	HOOD	TX2210003.16	BRIDGET KEAN	1/9/2012	HOOD			2012-0001743
TX	HOOD	TX2210003.17	LUMMUS FAMILY INVESTMENTS LP	4/24/2012	HOOD			2012-0004852
TX	HOOD	TX2210003.18	RCPTX, LTD	4/12/2012	HOOD			2012-0004589
TX	HOOD AND JOHNSON	TX2210006.01	MICHAEL MOONEY ET UX	4/2/2003	HOOD	1909	69	17436
TX	HOOD AND JOHNSON	TX2210006.01	MICHAEL MOONEY ET UX	4/2/2003	JOHNSON	3050	480	6760
TX	HOOD AND JOHNSON	TX2210006.02	MELODY TUCHIN BELZ	1/15/2004	HOOD	1987	569	3007
TX	HOOD AND JOHNSON	TX2210006.02	MELODY TUCHIN BELZ	1/15/2004	JOHNSON	3240	520	6802
TX	HOOD AND JOHNSON	TX2210006.03	MICHAEL TUCHIN	2/4/2004	HOOD	1984	645	2345
	HOOD AND JOHNSON	TX2210006.03	MICHAEL TUCHIN	2/4/2004	JOHNSON	3237	94	6227
TX	HOOD AND JOHNSON	TX2210006.04	HEATHER BELZ	8/22/2007	JOHNSON	4212	273	45291
TX	HOOD AND JOHNSON	TX2210006.04	HEATHER BELZ	8/22/2007
TX	HOOD AND JOHNSON	TX2210006.05	JENNIFER BELZ	8/22/2007	JOHNSON	4212	269	45290
TX	HOOD AND JOHNSON	TX2210006.05	JENNIFER BELZ	8/22/2007
TX	HOOD AND JOHNSON	TX2210006.06	TIM J CECIL	12/22/2007	JOHNSON	4267	263	722
TX	HOOD AND JOHNSON	TX2210006.06	MARGARET S DEAR ET VIR	12/22/2007
TX	HOOD, JOHNSON AND SOMERVELL	TX2210006.07	WALTER E PARKER ET AL	2/20/2003	HOOD	1917	324	8589
TX	HOOD, JOHNSON AND SOMERVELL	TX2210006.07	WALTER E PARKER ET AL	2/20/2003	JOHNSON	3040	609	34443
TX	HOOD, JOHNSON AND SOMERVELL	TX2210006.07	WALTER E PARKER ET AL	2/20/2003	SOMERVELL	110	183	15685
TX	HOOD, JOHNSON AND SOMERVELL	TX2210006.08	CAULTHROPE S HINTON ET UX	6/10/2003	HOOD	1939	515	13043
TX	HOOD, JOHNSON AND SOMERVELL	TX2210006.08	CAULTHROPE S HINTON ET UX	6/10/2003	JOHNSON	3114	593	28538
TX	HOOD, JOHNSON AND SOMERVELL	TX2210006.08	CAULTHROPE S HINTON ET UX	6/10/2003	SOMERVELL	115	251	35324
TX	HOOD	TX2210007.00	J B RANDLE ET AL	4/1/2003	HOOD	1909	36	6755
TX	HOOD	TX2210008.01	LEE KAY DURHAM	4/1/2003	HOOD	1909	75	6761
TX	HOOD	TX2210008.02	STETSON MASSEY JR ET UX	4/1/2003	HOOD	1909	60	6759
TX	HOOD	TX2210010.01	SHERRY E MARSHALL POMYKAL	3/27/2003	HOOD	1911	560	7315
TX	HOOD	TX2210010.02	MARSHALL SAMUEL MEEK	3/27/2003	HOOD	1911	564	7317
TX	HOOD	TX2210010.03	DEBORAH L MARSHALL SCHERER	3/27/2003	HOOD	1911	562	7316
TX	HOOD	TX2210010.04	JOSEPHINE B THOMSON	1/12/2004	HOOD	1980	549	1333
TX	HOOD	TX2210010.05	WILSON FAMILY LTD PART	1/12/2004	HOOD	1980	552	1334
TX	HOOD	TX2210010.06	ALAN CORY BENSON	1/12/2004	HOOD	1991	130	3832
TX	HOOD	TX2210010.07	JUAN GALLEGOS AVILA ET UX	3/1/2004	HOOD	1991	124	3830
TX	HOOD	TX2210010.08	JAMES W TILLEY ET UX	7/20/2004	HOOD	2028	271	12068
TX	HOOD	TX2210010.09	ROBERT C WAGNER ET UX	7/27/2004	HOOD	2032	304	12923
TX	HOOD	TX2210010.10	JIMMIE DOYLE REIMER ET UX	2/12/2005	HOOD	2083	246	3698
TX	HOOD	TX2210010.11	MICHAEL T QUIMBY	3/10/2005	HOOD	2100	460	7632
TX	HOOD	TX2210010.12	ROLAND J THOMASON ET UX	5/18/2005	HOOD	2106	111	8945
TX	HOOD	TX2210010.13	ALLAN PADDACK ET UX	5/18/2005	HOOD	2106	109	8944
TX	HOOD	TX2210010.14	DAVID S UMPHRESS SR ET UX	7/6/2004	HOOD	2028	295	12077
TX	HOOD	TX2210010.15	DAVID S UMPHRESS SR ET UX	7/6/2004	HOOD	2051	353	17552
TX	HOOD	TX2210010.16	PHIL WADDELL / JANA BLANCO	2/5/2006	HOOD	2093	344	5911
TX	HOOD	TX2210011.00	JAMES ROBERT HILL	4/15/2003	HOOD	1914	277	7953
TX	HOOD	TX2210013.00	GRADY JOHN LEWIS	4/22/2003	HOOD	1914	265	7951
TX	HOOD	TX2210015.01	TIM J CECIL	4/30/2003	HOOD	1914	255	7949
TX	HOOD AND JOHNSON	TX2210016.01	JOE LANGDON ET UX	4/16/2003	HOOD	1917	348	8596
TX	HOOD AND JOHNSON	TX2210016.01	JOE LANGDON ET UX	4/16/2003	JOHNSON	3454	536	1766
TX	HOOD	TX2210016.02	LILLIE STEWART INGRAM	5/16/2003	HOOD	1927	192	10492
TX	HOOD	TX2210016.03	LILLIE STEWART INGRAM	5/16/2003	HOOD	1927	196	10493
TX	HOOD	TX2210016.04	MCGILVERY LAUREL	7/9/2003	HOOD	1935	288	12138
TX	HOOD	TX2210016.04	MCGILVERY LAUREL	7/9/2003
TX	HOOD AND JOHNSON	TX2210016.05	JACK LANGDON TRUST ET AL	6/12/2003	HOOD	1937	601	12652
TX	HOOD AND JOHNSON	TX2210016.05	JACK LANGDON TRUST ET AL	6/12/2003	JOHNSON	3454	547	1767
TX	HOOD AND JOHNSON	TX2210016.06	LANGDON JR JAMES C ET UX	12/10/2003	HOOD	1987	582	3011
TX	HOOD AND JOHNSON	TX2210016.06	LANGDON JR JAMES C ET UX	12/10/2003	JOHNSON	3665	848	40285
TX	HOOD	TX2210016.07	WALLACE A CLINES ET UX	1/18/2005	HOOD	2073	190	1460
TX	HOOD	TX2210016.08	LILLIE STEWART INGRAM	8/20/2007	HOOD	2341	277	18176
TX	HOOD	TX2210016.09	JOSEPH S LANGDON ET UX	10/13/2008	HOOD	2434	402	16617
TX	HOOD AND SOMERVELL	TX2210017.01	STETSON MASSEY JR ET AL	5/6/2003	SOMERVELL	111	329	34633
TX	HOOD AND SOMERVELL	TX2210017.01	STETSON MASSEY JR ET AL	5/6/2003	HOOD	1917	321	8588
TX	HOOD AND SOMERVELL	TX2210017.01	STETSON MASSEY JR ET AL	5/6/2003
TX	HOOD AND SOMERVELL	TX2210017.01	STETSON MASSEY JR ET AL	5/6/2003
TX	HOOD AND SOMERVELL	TX2210017.01	STETSON MASSEY JR ET AL	5/6/2003
TX	HOOD AND SOMERVELL	TX2210017.01	STETSON MASSEY JR ET AL	5/6/2003
TX	HOOD AND SOMERVELL	TX2210017.01	STETSON MASSEY JR ET AL	5/6/2003
TX	HOOD AND SOMERVELL	TX2210017.01	STETSON MASSEY JR ET AL	5/6/2003
TX	HOOD AND SOMERVELL	TX2210017.01	STETSON MASSEY JR ET AL	5/6/2003
TX	HOOD AND SOMERVELL	TX2210017.01	STETSON MASSEY JR ET AL	5/6/2003
TX	HOOD AND SOMERVELL	TX2210017.01	STETSON MASSEY JR ET AL	5/6/2003
TX	HOOD AND SOMERVELL	TX2210017.01	STETSON MASSEY JR ET AL	5/6/2003
TX	HOOD AND SOMERVELL	TX2210017.01	STETSON MASSEY JR ET AL	5/6/2003
TX	HOOD AND SOMERVELL	TX2210017.01	STETSON MASSEY JR ET AL	5/6/2003
TX	HOOD AND SOMERVELL	TX2210017.01	STETSON MASSEY JR ET AL	5/6/2003
TX	HOOD	TX2210017.02	EDDY BRYANT	4/28/2004	HOOD	2009	38	7853
TX	HOOD	TX2210017.03	JOHNNIE FAYE HUGGINS	4/30/2004	HOOD	2009	34	7852
TX	HOOD	TX2210017.04	STEWART DOROTHY	4/29/2004	HOOD	2009	26	7850
TX	HOOD AND SOMERVELL	TX2210017.05	STEWART ROGER	4/29/2004	HOOD	2009	22	7849
TX	HOOD AND SOMERVELL	TX2210017.05	STEWART ROGER	4/29/2004	SOMERVELL
TX	HOOD	TX2210017.06	NORMA HULSEY TEMPLE	5/18/2004	HOOD	2013	590	8687
TX	HOOD AND SOMERVELL	TX2210017.07	JUDY OWENS	4/29/2004	HOOD	2009	30	7851
TX	HOOD AND SOMERVELL	TX2210017.07	JUDY OWENS	4/29/2004	SOMERVELL
TX	HOOD AND SOMERVELL	TX2210017.08	ROGER STEWART ET AL	4/29/2004	HOOD	2013	604	8693
TX	HOOD AND SOMERVELL	TX2210017.08	ROGER STEWART ET AL	4/29/2004	SOMERVELL
TX	HOOD AND SOMERVELL	TX2210017.09	WILLIAM H WILSON	5/29/2004	HOOD	2021	393	10444
TX	HOOD AND SOMERVELL	TX2210017.09	WILLIAM H WILSON	5/29/2004	SOMERVELL
TX	HOOD AND SOMERVELL	TX2210017.10	JEANETTE WAI IND & TRUSTEE	11/2/2004	HOOD	2059	771	19471
TX	HOOD AND SOMERVELL	TX2210017.10	JEANETTE WAI IND & TRUSTEE	11/2/2004	SOMERVELL	135	679	39281
TX	HOOD	TX2210017.11	MILDRED BROCK PARKER ETVIR	4/25/2005	HOOD	2105	832	8865
TX	HOOD	TX2210017.12	LEWIS EARL WAYNE	4/22/2003	HOOD	1914	271	7952
TX	HOOD	TX2210017.13	GIBBS DOROTHY PINSON	4/22/2003	HOOD	1914	259	7950
TX	HOOD AND SOMERVELL	TX2210017.14	TEXAS OSAGE ROYALTY POOL	5/15/2008	HOOD	2408	482	10421
TX	HOOD AND SOMERVELL	TX2210017.14	TEXAS OSAGE ROYALTY POOL	5/15/2008	SOMERVELL			20081871
TX	HOOD AND SOMERVELL	TX2210017.15	WILLIAM RICHARD BUSH ET UX	8/6/2004	HOOD	2038	279	38427
TX	HOOD AND SOMERVELL	TX2210017.15	WILLIAM RICHARD BUSH ET UX	8/6/2004	SOMERVELL	131	424	14374
TX	HOOD AND SOMERVELL	TX2210017.15	WILLIAM RICHARD BUSH ET UX	8/6/2004
TX	HOOD AND SOMERVELL	TX2210017.16	BRYANT EDDY	5/12/2010	HOOD	2548	349	6138
TX	HOOD AND SOMERVELL	TX2210017.16	BRYANT EDDY	5/12/2010	SOMERVELL			20101048
TX	HOOD AND SOMERVELL	TX2210017.17	WILLIAM H WILSON	5/21/2010	HOOD			2010-0006519
TX	HOOD AND SOMERVELL	TX2210017.17	WILLIAM H WILSON	5/21/2010	SOMERVELL			20101045
TX	HOOD AND SOMERVELL	TX2210017.18	DENISE GROSS	5/28/2010	HOOD			2010-0006904
TX	HOOD AND SOMERVELL	TX2210017.18	DENISE GROSS	5/28/2010	SOMERVELL			20101098
TX	HOOD AND SOMERVELL	TX2210017.19	DOROTHY STEWART	5/28/2010	HOOD			2010-0006906
TX	HOOD AND SOMERVELL	TX2210017.19	DOROTHY STEWART	5/28/2010	SOMERVELL			20101100
TX	HOOD AND SOMERVELL	TX2210017.20	ROGER STEWART	5/28/2010	HOOD			2010-0006905
TX	HOOD AND SOMERVELL	TX2210017.20	ROGER STEWART	5/28/2010	SOMERVELL			20101099
TX	HOOD AND SOMERVELL	TX2210017.21	JOHNNIE FAYE HUGGINS	5/25/2010	HOOD			2010-0006520
TX	HOOD AND SOMERVELL	TX2210017.21	JOHNNIE FAYE HUGGINS	5/25/2010	SOMERVELL			20101046
TX	HOOD AND SOMERVELL	TX2210017.22	VICKI YU	5/14/2010	HOOD			2010-0006901
TX	HOOD AND SOMERVELL	TX2210017.22	VICKI YU	5/14/2010	SOMERVELL			20101095
TX	HOOD AND SOMERVELL	TX2210017.23	JEANETTE WAI	5/14/2010	HOOD			2010-0006902
TX	HOOD AND SOMERVELL	TX2210017.23	JEANETTE WAI	5/14/2010	SOMERVELL			20101096
TX	HOOD AND SOMERVELL	TX2210017.24	NORMA HULSEY TEMPLE	5/26/2010	HOOD			2010-0006907
TX	HOOD AND SOMERVELL	TX2210017.24	NORMA HULSEY TEMPLE	5/26/2010	SOMERVELL			20101101
TX	HOOD AND SOMERVELL	TX2210017.25	LORETTA QUON ENG	5/14/2010	HOOD			2010-0006903
TX	HOOD AND SOMERVELL	TX2210017.25	LORETTA QUON ENG	5/14/2010	SOMERVELL			20101097
TX	HOOD AND SOMERVELL	TX2210017.26	JUDY WOODALL	6/16/2010	HOOD			2010-0007753
TX	HOOD AND SOMERVELL	TX2210017.26	JUDY WOODALL	6/16/2010	SOMERVELL			20101197
TX	HOOD AND SOMERVELL	TX2210017.27	UNITED CHURCH OF GOD	5/12/2010	HOOD			2010-0009317
TX	HOOD AND SOMERVELL	TX2210017.27	UNITED CHURCH OF GOD	5/12/2010	SOMERVELL			20101439
TX	HOOD AND SOMERVELL	TX2210017.28	DEVON ENERGY PRODUCTION	10/26/2010	HOOD			2010-0013013
TX	HOOD AND SOMERVELL	TX2210017.28	DEVON ENERGY PRODUCTION	10/26/2010	SOMERVELL			20110086
TX	HOOD	TX2210018.00	HOPKINS RAYMOND ET UX TRE	4/25/2003	HOOD	1916	127	8354
TX	HOOD	TX2210019.01	NANCY P FISH	5/1/2003	HOOD	1917	344	8594
TX	HOOD	TX2210019.02	GARY M PUTTEET	5/1/2003	HOOD	1917	342	8593
TX	HOOD	TX2210019.02	GARY M PUTTEET	5/1/2003
TX	HOOD	TX2210020.00	HEWITT ALTON L ET UX	5/26/2003	HOOD	1920	318	9174
TX	HOOD	TX2210021.00	PARRISH WILLIAM C ET UX	5/27/2003	HOOD	1923	17	9660
TX	HOOD	TX2210022.00	JOHNSON HERBERT ET UX REV	5/21/2003	HOOD	1923	12	9659
TX	HOOD	TX2210024.01	STETSON MASSEY JR ET UX	5/14/2003	HOOD	1920	320	9175
TX	HOOD	TX2210024.01	STETSON MASSEY JR ET UX	5/14/2003
TX	HOOD	TX2210024.14	SAMUEL D BOWDEN	11/2/2007	HOOD	2367	743	978
TX	HOOD	TX2210024.15	WILLIAM ROWDY RIDDLE ET UX	4/18/2007	HOOD	2318	314	12849
TX	HOOD	TX2210024.16	JOSHUA HALE RIDDLE ET UX	4/18/2007	HOOD	2318	316	12850
TX	HOOD	TX2210024.17	MARILYN GARDNER	5/1/2007	HOOD	2305	970	9984
TX	HOOD	TX2210024.18	MEREDITH BOWDEN	5/1/2007	HOOD	2305	966	9982
TX	HOOD	TX2210024.19	CHRISTOPHER BOWDEN	5/1/2007	HOOD	2305	968	9983
TX	HOOD	TX2210024.20	CATHERINE BOWDEN	5/1/2007	HOOD	2308	945	10643
TX	HOOD AND SOMERVELL	TX2210026.01	SADLER SHARRON KINNARD	5/23/2003	HOOD	1925	178	10090
TX	HOOD AND SOMERVELL	TX2210026.01	SADLER SHARRON KINNARD	5/23/2003	SOMERVELL	112	439	34835
TX	HOOD AND SOMERVELL	TX2210026.02	KINNARD JAKE DARLAN	5/23/2003	HOOD	1925	168	10089
TX	HOOD AND SOMERVELL	TX2210026.02	KINNARD JAKE DARLAN	5/23/2003	SOMERVELL	112	419	34833
TX	HOOD AND SOMERVELL	TX2210026.03	ROGERS SANDRA KAY KINNARD	5/23/2003	SOMERVELL	112	428	34834
TX	HOOD AND SOMERVELL	TX2210026.03	ROGERS SANDRA KAY KINNARD	5/23/2003	HOOD	1925	157	10088
TX	HOOD AND SOMERVELL	TX2210026.04	KINNARD DARRELL WAYNE	5/23/2003	HOOD	1925	188	10091
TX	HOOD AND SOMERVELL	TX2210026.04	KINNARD DARRELL WAYNE	5/23/2003	SOMERVELL	112	448	34836
TX	HOOD AND SOMERVELL	TX2210027.00	STINSON BYRON ET UX	5/30/2003	HOOD	1927	202	10495
TX	HOOD AND SOMERVELL	TX2210027.00	STINSON BYRON ET UX	5/30/2003	SOMERVELL	112	767	34897
TX	HOOD	TX2210028.00	BYRL & ROBBIE HAYWORTH TR	6/18/2003	HOOD	1925	153	10087
TX	HOOD	TX2210028.00	BYRL & ROBBIE HAYWORTH TR	6/18/2003
TX	HOOD	TX2210029.00	HAYWORTH BOB ET UX	7/8/2003	HOOD	1930	696	11210
TX	HOOD	TX2210030.00	WALL JOSEPH MICHAEL ET AL	6/19/2003	HOOD	1928	885	10814
TX	HOOD	TX2210030.99	JOSEPH MICHAEL WALL ET AL	7/26/2004	HOOD	2028	992	12216
TX	HOOD	TX2210031.00	TWO-O-FIVE CORPORATION	6/19/2003	HOOD	1927	190	10491
TX	HOOD	TX2210033.01	KIMMEL GERALD E ET UX	7/5/2003	HOOD	1930	682	11204
TX	HOOD	TX2210033.02	NONA KAY TIDWELL NICKEL	6/23/2005	HOOD	2119	426	11967
TX	HOOD	TX2210033.03	FRANCIS SUMMERS	6/30/2005	HOOD	2119	410	11961
TX	HOOD	TX2210033.04	KATHY PURSELLEY	6/30/2005	HOOD	2119	395	11956
TX	HOOD	TX2210033.05	KATIE LEE CLAWSON	7/6/2005	HOOD	2119	401	11958
TX	HOOD	TX2210033.06	SUE ANN COLE	7/6/2005	HOOD	2119	404	11959
TX	HOOD	TX2210033.07	HARRY FRANKLIN SHELTON	7/6/2005	HOOD	2119	407	11960
TX	HOOD	TX2210033.08	ANDERSON LUKE RASH	7/6/2005	HOOD	2119	398	11957
TX	HOOD	TX2210033.09	MARTHA CHRISTINE MCKINNEY	7/6/2005	HOOD	2119	413	11962
TX	HOOD	TX2210033.10	JIMMY DWAIN TIDWELL	7/7/2005	HOOD	2120	254	12126
TX	HOOD	TX2210033.11	TED E BREWER	7/19/2005	HOOD	2125	869	13342
TX	HOOD	TX2210033.12	THOMAS VERNON GILLEN	7/18/2005	HOOD	2125	862	13340
TX	HOOD	TX2210033.13	DONNA KAY WERNER	7/19/2005	HOOD	2128	98	13829
TX	HOOD	TX2210033.14	RICHARD LEE BURCH EXEC	7/27/2005	HOOD	2128	95	13828
TX	HOOD	TX2210033.15	RICHARD LEE BURCH	6/23/2005	HOOD	2128	92	13827
TX	HOOD	TX2210033.16	NELDA GRACE HACKETT	6/23/2005	HOOD	2128	89	13826
TX	HOOD	TX2210033.17	DELAINE DUNN	7/15/2005	HOOD	2129	815	14237
TX	HOOD	TX2210033.18	MICKI DUNN	7/15/2005	HOOD	2129	818	14238
TX	HOOD	TX2210033.19	GEORGE REED	7/19/2005	HOOD	2129	821	14239
TX	HOOD	TX2210033.20	MICKI DUNN	2/22/2006	HOOD	2180	969	4004
TX	HOOD	TX2210033.21	NELDA GRACE HACKETT	3/1/2006	HOOD	2180	975	4006
TX	HOOD	TX2210033.22	DELAINE DUNN	2/22/2006	HOOD	2180	972	4005
TX	HOOD	TX2210033.23	THOMAS VERNON GILLEN	2/28/2006	HOOD	2180	960	4001
TX	HOOD	TX2210033.24	GEORGE REED	2/28/2006	HOOD	2180	966	4003
TX	HOOD	TX2210033.25	JIMMY DWAIN TIDWELL	2/23/2006	HOOD	2180	963	4002
TX	HOOD	TX2210033.26	ANDERSON LUKE RASH	2/22/2006	HOOD	2180	939	3994
TX	HOOD	TX2210033.27	NONA KAY NICKEL	2/24/2006	HOOD	2180	942	3995
TX	HOOD	TX2210033.28	KATHY PURSELLEY	2/23/2006	HOOD	2180	945	3996
TX	HOOD	TX2210033.29	FRANCIS SUMMERS	2/23/2006	HOOD	2180	948	3997
TX	HOOD	TX2210033.30	SUE ANN COLE	2/22/2006	HOOD	2180	951	3998
TX	HOOD	TX2210033.31	MARTHA CHRISTINE MCKINNEY	2/22/2006	HOOD	2180	951	3999
TX	HOOD	TX2210033.32	KATIE LEE CLAWSON	2/22/2006	HOOD	2180	957	4000
TX	HOOD	TX2210033.33	DONNA KAY WERNER	2/28/2006	HOOD	2182	468	4416
TX	HOOD	TX2210033.34	R L BURCH IND/EX EST BURCH	3/6/2006	HOOD	2186	151	5365
TX	HOOD	TX2210033.35	A L RASH AIF H F SHELTON	3/20/2006	HOOD	2186	138	5360
TX	HOOD	TX2210033.36	ELIZABETH ANN GOLEMON	3/15/2006	HOOD	2186	135	5359
TX	HOOD	TX2210033.38	CATHY PHILIPSKI ET VIR	5/1/2007	HOOD	2304	620	9557
TX	HOOD	TX2210033.39	SHERI L SEARS ET VIR	5/1/2007	HOOD	2318	284	12835
TX	HOOD	TX2210033.40	RANDLE MURRAY	4/1/2003	HOOD	1909	45	6756
TX	HOOD	TX2210034.00	HAYWORTH JOHN D ET UX	7/8/2003	HOOD	1930	694	11209
TX	HOOD	TX2210037.01	HOUSE OMARIE TAL' F ET AL	6/5/2003	HOOD	1930	684	11205
TX	HOOD	TX2210037.01	HOUSE OMARIE TAL' F ET AL	6/5/2003
TX	HOOD	TX2210037.01	HOUSE OMARIE TAL' F ET AL	6/5/2003
TX	HOOD	TX2210037.01	HOUSE OMARIE TAL' F ET AL	6/5/2003
TX	HOOD	TX2210037.01	HOUSE OMARIE TAL' F ET AL	6/5/2003
TX	HOOD	TX2210037.02	CRABTREE LIVING TRUST	3/22/2004	HOOD	2028	274	12069
TX	HOOD	TX2210037.03	RICHARD W ODNEAL ET UX	10/21/2004	HOOD	2096	44	6576
TX	HOOD	TX2210037.04	ROBERT EDWARD LYONS III	3/31/2008	HOOD	2396	19	7512
TX	HOOD	TX2210038.00	WHEELER DAVID V ET UX	7/8/2003	HOOD	1935	284	12137
TX	HOOD	TX2210039.00	REED GLEEN DORA	6/11/2003	HOOD	1935	278	12136
TX	HOOD	TX2210041.01	LESLIE MABERY ET UX	7/7/2003	HOOD	1930	689	11207
TX	HOOD	TX2210041.04	CAROL RHOADES SEALEY	4/30/2008	HOOD	2405	703	9822
TX	HOOD	TX2210041.05	PHYLLIS LYNN DAVIS	4/30/2008	HOOD	2405	699	9820
TX	HOOD	TX2210041.06	KELLY SEALEY HOPPER	4/30/2008	HOOD	2405	701	9821
TX	HOOD	TX2210041.09	LLM MINERALS LP	2/15/2010	HOOD	2534	365	2812
TX	HOOD	TX2210041.10	JERRY'S CHEVROLET EMPLOYEE'S	10/14/2010	HOOD			2010-0012886
TX	HOOD	TX2210041.11	FORREST F AVEN ET UX	10/14/2010	HOOD			2010-0012887
TX	HOOD	TX2210041.12	DAVID THOMPSON ET UX	10/14/2010	HOOD			2010-0013112
TX	HOOD	TX2210042.00	NACE BRYAN A ET UX	7/17/2003	HOOD	1937	603	12653
TX	HOOD	TX2210043.01	DORA LEE LANGDON ART V TR	8/1/2003	HOOD	1937	599	12651
TX	HOOD	TX2210043.02	ROLLINS JOHNNIE ET UX	9/4/2003	HOOD	1954	539	16330
TX	HOOD	TX2210043.03	JACK LANGDON TRUST 'A'	7/5/2006	HOOD	2218	482	12881
TX	HOOD	TX2210043.04	STEPHEN D REINKE ET UX	4/25/2007	HOOD	2300	799	8624
TX	HOOD	TX2210043.05	GLENN E BURTON ET UX	4/21/2007	HOOD	2300	801	8625
TX	HOOD	TX2210043.06	DANNY K THOMAS ET UX	4/26/2007	HOOD	2308	922	10634
TX	HOOD	TX2210043.07	DENISE CHIROS LODATO TSTEE	5/1/2007	HOOD	2318	277	12832
TX	HOOD	TX2210043.08	NANCY M ADAMSON	5/1/2007	HOOD	2318	302	12844
TX	HOOD	TX2210043.09	R SPRAGUE/S SPRAGUE TSTEES	5/1/2007	HOOD	2318	304	12845
TX	HOOD	TX2210043.10	WAYNE L COYER ET UX	5/31/2007	HOOD	2318	298	12842
TX	HOOD	TX2210043.11	WILLIAM R LISTON ET UX	5/1/2007	HOOD	2318	306	12846
TX	HOOD	TX2210043.12	BRETT C RODGERS ET UX	5/1/2007	HOOD	2318	300	12843
TX	HOOD	TX2210043.13	MARC S POWELL TRUSTEE	5/1/2007	HOOD	2322	776	13879
TX	HOOD	TX2210043.14	WILLIAM BLACK ET UX	5/1/2007	HOOD	2318	231	12813
TX	HOOD	TX2210043.15	DENNIS SACKETT ET UX	5/1/2007	HOOD	2318	275	12831
TX	HOOD	TX2210043.16	RICHARD KATZ ET UX	5/1/2007	HOOD	2322	778	13880
TX	HOOD	TX2210043.17	FRANCIS & DOROTHY CHIROS	5/1/2007	HOOD	2322	780	13881
TX	HOOD	TX2210043.18	ROY E & ROBIN L JARRETT	5/1/2007	HOOD	2318	225	12810
TX	HOOD	TX2210043.19	DOROTHY STEVENS TRUSTEE	5/1/2007	HOOD	2322	774	13878
TX	HOOD	TX2210043.20	SCOTT B ADAMSON ET UX	5/1/2007	HOOD	2318	227	12811
TX	HOOD	TX2210043.21	CHRISTOPHER ADAMSON ET UX	5/1/2007	HOOD	2318	229	12812
TX	HOOD	TX2210043.22	NICHOLSON FAMILY TRUST	5/1/2007	HOOD	2322	770	13876
TX	HOOD	TX2210043.23	KARYN L FOX ET VIR	5/1/2007	HOOD	2322	763	13873
TX	HOOD	TX2210043.24	CHRIS WOODSON ET UX	5/1/2007	HOOD	2322	768	13875
TX	HOOD	TX2210043.25	GARY PRINCE REV TR	5/1/2007	HOOD	2322	772	13877
TX	HOOD	TX2210043.26	ALLEN FAMILY TRUST	5/1/2007	HOOD	2322	765	13874
TX	HOOD	TX2210043.27	TEXAS LONGHORN EQUITIES	5/1/2007	HOOD	2322	973	13931
TX	HOOD	TX2210043.28	GARY & DIANE PRINCE TSTEES	5/1/2007	HOOD	2334	17	16451
TX	HOOD	TX2210043.29	ST TX 108055	7/17/2007	HOOD	2334	19	16452
TX	HOOD	TX2210043.30	GRANBURY ISD	4/20/2007	HOOD	2305	754	9879
TX	HOOD	TX2210043.30	GRANBURY ISD	4/20/2007
TX	HOOD	TX2210043.31	DONALD B CAMPBELL	7/4/2006	HOOD	2231	650	15908
TX	HOOD	TX2210043.33	ROBERT F TAYLOR ET UX	6/23/2006	HOOD	2220	220	13306
TX	HOOD	TX2210043.35	NELDA GOIN	6/23/2006	HOOD	2220	212	13302
TX	HOOD	TX2210043.36	WILLIAM ROEHMER ET UX	6/23/2006	HOOD	2220	196	13294
TX	HOOD	TX2210043.37	TERRY VENABLE ET UX	6/23/2006	HOOD	2220	202	13297
TX	HOOD	TX2210043.38	RAYMOND SLIVA ET UX	6/23/2006	HOOD	2220	214	13303
TX	HOOD	TX2210043.40	WILLIAM FRED TUCKER ET UX	6/23/2006	HOOD	2220	228	13310
TX	HOOD	TX2210043.42	JERRY R SINGLETON ET UX	6/23/2006	HOOD	2220	206	13299
TX	HOOD	TX2210043.42	JERRY R SINGLETON ET UX	6/23/2006
TX	HOOD	TX2210043.44	GARRY LYNN GRAY ET UX	6/23/2006	HOOD	2220	194	13293
TX	HOOD	TX2210043.45	JOHN DAVIS ET UX	6/25/2006	HOOD	2223	695	14075
TX	HOOD	TX2210043.46	BRUNO J GLATZEL	6/23/2006	HOOD	2223	720	14086
TX	HOOD	TX2210043.49	TAMMYE H HEALER ET UX	6/29/2006	HOOD	2220	218	13305
TX	HOOD	TX2210043.50	RUFUS P MCKENZIE ET UX	6/23/2006	HOOD	2220	216	13304
TX	HOOD	TX2210043.51	BETTY E TAYLOR ET UX	7/10/2006	HOOD	2220	222	13307
TX	HOOD	TX2210043.53	STANLEY BREWER ET UX	6/23/2006	HOOD	2223	699	14077
TX	HOOD	TX2210043.54	GERALD DEROOS ET UX	6/29/2006	HOOD	2223	693	14074
TX	HOOD	TX2210043.58	J C CAMPBELL IND & TSTEE	7/14/2006	HOOD	2223	718	14085
TX	HOOD	TX2210043.58	J C CAMPBELL IND & TSTEE	7/14/2006
TX	HOOD	TX2210043.59	JERRY A CAMPBELL	7/14/2006	HOOD	2223	716	14084
TX	HOOD	TX2210043.61	BEVERLY B DAVIS	7/24/2006	HOOD	2223	687	14071
TX	HOOD	TX2210043.64	LINDA WILCOX	8/30/2006	HOOD	2236	779	17117
TX	HOOD	TX2210043.65	JERRY LEAKE ET UX	9/25/2006	HOOD	2257	987	21968
TX	HOOD	TX2210043.66	JAMES MICHAEL WOOTEN ET UX	11/21/2006	HOOD	2270	63	1401
TX	HOOD	TX2210043.68	JAMES LOYD GRIDER JR	11/1/2006	HOOD	2293	569	6997
TX	HOOD	TX2210043.74	RITA A TILLEY	4/8/2009	HOOD	2478	759	6561
TX	HOOD	TX2210043.75	BEULAH IVEY	5/7/2009	HOOD	2485	683	8157
TX	HOOD	TX2210043.76	WILLSHER PROPERTIES LLC	4/27/2009	HOOD	2485	672	8153
TX	HOOD	TX2210043.78	NICHOLAS CANGIAMILLA JR ET	5/1/2009	HOOD	2506	505	13173
TX	HOOD	TX2210043.79	HELEN A FARCAS IND & AIF	10/5/2009	HOOD	2518	658	16188
TX	HOOD	TX2210043.80	JUSRYN COMPANY INC	2/12/2010	HOOD	2534	359	2810
TX	HOOD	TX2210043.81	ARNOLD C JAMES ET UX	1/19/2010	HOOD	2534	386	2820
TX	HOOD	TX2210043.82	LOUIS EUGENE MASSENGALE ET UX	4/20/2010	HOOD	2541	764	4614
TX	HOOD	TX2210043.83	JANET KAY MARION MILLER	4/14/2010	HOOD	2545	965	5588
TX	HOOD	TX2210043.84	BILLY MAX WARNICK ET UX	8/18/2010	HOOD			2010-0011460
TX	HOOD	TX2210043.85	SEVENTH DAY ADVENTIST	12/6/2010	HOOD			2011-0000424
TX	HOOD	TX2210043.86	ROBERT VERNON BAGWELL ET UX	7/18/2011	HOOD			2011-0008751
TX	HOOD	TX2210043.87	JAMES LYNN BAGWELL ET UX	7/15/2011	HOOD			2011-0008750
TX	HOOD	TX2210043.89	MICHAEL S WARNICK	9/10/2011	HOOD			2011-0010187
TX	HOOD	TX2210043.90	LARRY GENE TILLEY	11/1/2011	HOOD			2011-0012913
TX	HOOD	TX2210043.91	LARRY GENE TILLEY	2/4/2012	HOOD			2012-0002215
TX	HOOD	TX2210043.92	JOHNNY T HARRIS ET UX	4/12/2010	HOOD	2541	827	4632
TX	HOOD	TX2210044.00	PUTTEET REV TRUST ET AL	8/1/2003	HOOD	1937	596	12650
TX	HOOD	TX2210048.00	WALLACE BILLY JOE ET UX	7/12/2003	HOOD	1939	528	13047
TX	HOOD	TX2210049.01	BECK RAYMOND EDWARD ET UX	8/2/2003	HOOD	1939	520	13044
TX	HOOD	TX2210049.01	BECK RAYMOND EDWARD ET UX	8/2/2003
TX	HOOD	TX2210050.01	LEO POTISHMAN FOUNDATION	6/27/2003	HOOD	1935	300	12140
TX	HOOD	TX2210050.02	KATHERINE CAMPOS	1/30/2004	HOOD	1996	316	5042
TX	HOOD	TX2210051.00	BOLTON JERREL E ET AL	7/17/2003	HOOD	1949	679	15206
TX	HOOD	TX2210052.00	DURANT FAM'LY IRREV TR	7/17/2003	HOOD	1949	681	15207
TX	HOOD	TX2210055.01	HUBBARD H L ET UX	8/7/2003	HOOD	1945	902	14345
TX	HOOD	TX2210056.01	FINLEY NORA DE ALVA MOORE	8/16/2003	HOOD	1945	883	14341
TX	HOOD	TX2210056.01	FINLEY NORA DE ALVA MOORE	8/16/2003
TX	HOOD	TX2210057.01	RUTH ELLEN BROWN ET AL	8/7/2003	HOOD	1941	114	13364
TX	HOOD	TX2210057.02	WILLIAM PANNILL AYCOCK	2/1/2005	HOOD	2076	672	2227
TX	HOOD	TX2210057.03	EDWARD S AYCOCK	2/1/2005	HOOD	2077	757	2485
TX	HOOD	TX2210058.00	PATTERSON TANYA ET AL	8/29/2003	HOOD	1949	685	15209
TX	HOOD	TX2210059.00	WITHERSPOON III CLAUDE ETU	8/29/2003	HOOD	1949	687	15210
TX	HOOD	TX2210060.01	G & M LAND & CATTLE CO	8/29/2003	HOOD	1949	689	15211
TX	HOOD	TX2210060.02	SHARP LLOYD H	8/13/2003	HOOD	1954	563	16341
TX	HOOD	TX2210060.03	SHARP HAZEL/L SHARP A/I/F	8/13/2003	HOOD	1954	561	16340
TX	HOOD	TX2210060.04	KENNETH W CAUSEY ET UX	11/7/2003	HOOD	1969	384	19783
TX	HOOD	TX2210060.05	ROBERT EARL DAVIS ET UX	11/7/2003	HOOD	1969	406	19792
TX	HOOD	TX2210060.06	BRYAN K CAUSEY ET UX	11/7/2003	HOOD	1969	381	19782
TX	HOOD	TX2210060.07	JAMES M KNAVEL	11/20/2003	HOOD	1969	378	19782
TX	HOOD	TX2210060.08	STEVEN B SMITH ET UX	11/7/2003	HOOD	1969	375	19781
TX	HOOD	TX2210060.09	HOWARD L SMITH ET UX	11/7/2003	HOOD	1969	372	19780
TX	HOOD	TX2210060.10	JOHNNY R WHITLEY ET UX	12/3/2003	HOOD	1971	799	20286
TX	HOOD	TX2210060.11	WILLIAM L NICHOLS ET UX	11/7/2003	HOOD	1969	387	19785
TX	HOOD	TX2210060.12	TINA MARIE HANSEN	8/17/2004	HOOD	2038	274	14372
TX	HOOD	TX2210061.00	ARCHIE JOE WHEAT	8/21/2003	HOOD	1949	691	15212
TX	HOOD	TX2210061.00	ARCHIE JOE WHEAT	8/21/2003
TX	HOOD	TX2210062.01	CHARLES R SNAKARD	7/30/2003	HOOD	1945	895	14344
TX	HOOD	TX2210062.02	LAURA S CROSBY	7/30/2003	HOOD	1945	889	14343
TX	HOOD	TX2210064.00	CAMP FIRE USA 1ST TEXAS	8/29/2003	HOOD	1949	695	15213
TX	HOOD	TX2210066.00	LARRY L CLARK ET UX	9/30/2003	HOOD	1956	588	16809
TX	HOOD	TX2210067.00	MILDRED LOUISE MCCLENDON	10/2/2003	HOOD	1961	626	17964
TX	HOOD	TX2210069.00	E F ALLISON ET UX	9/18/2003	HOOD	1956	612	16818
TX	HOOD	TX2210071.00	HARMON L ADAIR JR ET UX	9/22/2003	HOOD	1957	529	17042
TX	HOOD	TX2210072.00	THOMAS ROYCE HARBER ET UX	10/2/2003	HOOD	1956	590	16810
TX	HOOD	TX2210074.01	STEWART & DURANT CATTLE CO	7/17/2003	HOOD	1951	593	15660
TX	HOOD	TX2210074.02	JAMES W MENEFEE	8/30/2003	HOOD	1954	555	16337
TX	HOOD	TX2210074.03	WILLIAM FRANK HARRIS	8/26/2003	HOOD	1954	553	16336
TX	HOOD	TX2210074.04	MARY TOM HARRIS MENEFEE	8/30/2003	HOOD	1954	559	16339
TX	HOOD	TX2210074.05	DAVID L MENEFEE	8/30/2003	HOOD	1954	557	16338
TX	HOOD	TX2210074.06	WM LEE DESANDERS ET AL	6/5/2006	HOOD	2211	512	11236
TX	HOOD	TX2210075.01	DURANT GRANTOR TRUST A & B	7/17/2003	HOOD	1951	589	15658
TX	HOOD	TX2210075.01	DURANT GRANTOR TRUST A & B	7/17/2003
	HOOD	TX2210075.01	DURANT GRANTOR TRUST A & B	7/17/2003
TX	HOOD	TX2210075.02	BRUCE A AWALT	12/2/2006	HOOD	2277	175	3149
TX	HOOD	TX2210075.03	DAVID M AWALT	12/2/2006	HOOD	2277	173	3148
TX	HOOD	TX2210075.04	RICHARD EADES	12/12/2006	HOOD	2277	169	3146
TX	HOOD	TX2210075.05	DIANA EADES FRANKLIN	12/12/2006	HOOD	2277	171	3147
TX	HOOD	TX2210075.06	JACK D EADES JR	1/15/2007	HOOD	2281	985	4285
TX	HOOD	TX2210075.07	LORRAINE ELIZABETH EADES	1/15/2007	HOOD	2281	983	4284
TX	HOOD	TX2210078.00	FRANCES CUTTS IND & INDEP	8/29/2003	HOOD	1954	543	16332
TX	HOOD	TX2210079.00	JACK PATTERSON ET AL	8/29/2003	HOOD	1954	547	16334
TX	HOOD	TX2210080.00	METHODIST CHILDREN'S HOME	9/3/2003	HOOD	1954	541	16331
TX	HOOD	TX2210081.01	DENNIS R MINTER ET UX	8/30/2003	HOOD	1951	591	15659
TX	HOOD	TX2210081.02	METHODIST CHILDREN'S HOME	11/3/2003	HOOD	1964	808	18698
TX	HOOD	TX2210081.03	ACTON UNITED METHODIST CH	6/14/2004	HOOD	2055	739	18575
TX	HOOD	TX2210085.00	MABEL ROE	9/10/2003	HOOD	1964	810	18699
TX	HOOD	TX2210086.00	JACKIE W COURTNEY SR ET UX	10/23/2003	HOOD	1961	621	17962
TX	HOOD	TX2210088.00	STEVE N WILKERSON ET UX	9/15/2003	HOOD	1954	550	16335
TX	HOOD	TX2210089.01	SUNCHASE DEVELOPMENT CO	8/18/2003	HOOD	1966	250	19059
TX	HOOD	TX2210089.07	JON HARRIS STARNES ET UX	10/2/2007	HOOD	2354	958	21323
TX	HOOD	TX2210089.08	JEAN STARNES	10/1/2007	HOOD	2354	955	21322
TX	HOOD	TX2210089.09	BISHOP-WINDHAM FAMILY LP	1/2/2008	HOOD	2382	69	4146
TX	HOOD	TX2210089.11	ROBERT EARL DORRIS	8/5/2003	HOOD	1939	523	13045
TX	HOOD	TX2210089.14	MERILYN RUTH EVANS	3/5/2012	HOOD			2012-0002848
TX	HOOD	TX2210093.00	BILLY J ROLLINS ET UX	10/20/2003	HOOD	1963	736	18406
TX	HOOD	TX2210094.00	VICTORIA NADOLSKI YOUNG	9/30/2003	HOOD	1963	734	18405
TX	HOOD	TX2210095.00	RONALD JUDSON COONROD	9/30/2003	HOOD	1957	527	17041
TX	HOOD	TX2210096.00	CLINE FAMILY TRUST	9/23/2003	HOOD	1957	531	17043
TX	HOOD	TX2210097.01	LEONARD INVESTMENT ET AL	9/23/2003	HOOD	1956	603	16815
TX	HOOD	TX2210097.02	SHARON ANN BLAKNEY	2/6/2006	HOOD	2176	509	2980
TX	HOOD	TX2210097.03	DOROTHY SUE COLEMAN	2/6/2006	HOOD	2176	503	2978
TX	HOOD	TX2210097.04	TOMMY JAMES WALKER	2/6/2006	HOOD	2176	506	2979
TX	HOOD	TX2210097.05	LEXA STECKO, JUDITH SCOTT	4/5/2006	HOOD	2191	587	6576
TX	HOOD	TX2210098.00	LYNDA A WALLACE	10/22/2003	HOOD	1964	813	18700
TX	HOOD	TX2210100.01	JAMES HAROLD GILLIAM	10/2/2003	HOOD	1964	815	18701
TX	HOOD	TX2210100.02	JOSEPH BLANTON GILLIAM	10/2/2003	HOOD	1964	817	18702
TX	HOOD	TX2210100.03	ALLISON GLADYS GILLIAM	10/2/2003	HOOD	1964	819	18703
TX	HOOD	TX2210100.04	JAMES R ROBINSON ET UX	11/20/2003	HOOD	1971	806	20289
TX	HOOD	TX2210103.00	MRS W A MICKLE	11/12/2003	HOOD	1969	392	19787
TX	HOOD	TX2210104.01	MRS ALBERT GEE	10/10/2003	HOOD	1969	409	19793
TX	HOOD	TX2210104.02	ARTHUR PIERCE GEE	10/10/2003	HOOD	1969	411	19794
TX	HOOD	TX2210104.03	FLORA ETHEL TAYLOR	10/10/2003	HOOD	1969	413	19795
TX	HOOD	TX2210104.04	WILLENE GEE POYNOR	10/10/2003	HOOD	1969	415	19796
TX	HOOD	TX2210105.00	JULIAN C MASSEY ET UX	8/7/2003	HOOD	1957	524	17040
TX	HOOD	TX2210106.00	JULIAN C MASSEY ET UX	8/7/2003	HOOD	1957	521	17039
TX	HOOD	TX2210107.00	MAURINE CRAMER GILLILAND	10/10/2003	HOOD	1961	623	17963
TX	HOOD	TX2210110.01	EUGENE C WYATT	11/17/2003	HOOD	1969	400	19790
TX	HOOD	TX2210110.01	EUGENE C WYATT	11/17/2003
TX	HOOD	TX2210110.02	GRETA LOU VAUGHN NOBLE	1/22/2004	HOOD	1991	120	3829
TX	HOOD	TX2210113.00	CULP RANDA SUZANNE ET AL	10/8/2003	HOOD	1969	390	19786
TX	HOOD	TX2210114.00	LINDON M STEWART ET UX	8/7/2001	HOOD	1788	154	14515
TX	HOOD	TX2210114.00	LINDON M STEWART ET UX	8/7/2001
TX	HOOD AND SOMERVELL	TX2210116.00	ST TX M-103312	10/7/2003	SOMERVELL	119	829	36232
TX	HOOD AND SOMERVELL	TX2210116.00	ST TX M-103312	10/7/2003	HOOD	1969	417	19797
TX	HOOD AND JOHNSON	TX2210117.00	ST TX M-103311	10/7/2003	HOOD	1966	259	19061
TX	HOOD AND JOHNSON	TX2210117.00	ST TX M-103311	10/7/2003	JOHNSON	3221	268	3294
TX	HOOD AND SOMERVELL	TX2210118.00	LINDI GRISSOM GRANGER ETAL	11/22/2003	HOOD	1980	579	1343
TX	HOOD AND SOMERVELL	TX2210118.00	LINDI GRISSOM GRANGER ETAL	11/22/2003	SOMERVELL	121	738	36585
TX	HOOD	TX2210120.01	DAVID COGDILL	12/5/2003	HOOD	1972	694	20512
TX	HOOD	TX2210120.02	ALAN COGDILL	12/5/2003	HOOD	1972	684	20508
TX	HOOD	TX2210120.03	PATSY ANN COGDILL	12/10/2003	HOOD	1972	692	20511
TX	HOOD	TX2210120.04	STACY GENABEL W	12/9/2003	HOOD	1972	689	20510
TX	HOOD	TX2210120.05	WHITE DOROTHY MARIE	12/9/2003	HOOD	1972	686	20509
TX	HOOD	TX2210120.06	HUMPHRIES HULEN L ET UX	11/20/2003	HOOD	1977	466	558
TX	HOOD	TX2210120.07	WHITE JAMES DAVID	12/16/2003	HOOD	1977	442	547
TX	HOOD	TX2210120.08	WHITE ROGER DALE	12/16/2003	HOOD	1977	444	548
TX	HOOD	TX2210120.09	MORIN SANDRA W	1/29/2004	HOOD	1991	113	3826
TX	HOOD	TX2210120.11	LYNDON J BUSCH ET UX	6/1/2006	HOOD	2216	413	12408
TX	HOOD	TX2210120.12	K M WHITE & D L TAYLOR	9/15/2006	HOOD	2242	701	18458
TX	HOOD	TX2210120.13	DEBORAH LYNN TAYLOR	10/19/2006	HOOD	2255	613	21410
TX	HOOD	TX2210120.14	VICKIE DENISE SMITH	11/3/2006	HOOD	2257	993	21971
TX	HOOD	TX2210120.15	SUE ARMSTRONG KING	11/3/2006	HOOD	2257	997	21973
TX	HOOD	TX2210120.16	DEBORAH GAIL RUSSELL	11/3/2006	HOOD	2257	995	21972
TX	HOOD	TX2210120.17	MARSHA ANN VASS	11/3/2006	HOOD	2257	999	21974
TX	HOOD	TX2210120.18	BARBARA ANN SMITH	10/19/2006	HOOD	2281	887	4246
TX	HOOD	TX2210120.19	DORIS JENNETT GOEN	10/19/2006	HOOD	2281	891	4247
TX	HOOD	TX2210120.20	WANDA SUE BERRY	10/19/2006	HOOD	2281	883	4245
TX	HOOD	TX2210120.21	MARGIE MARIE BITTERS	10/19/2006	HOOD	2281	879	4244
TX	HOOD	TX2210120.22	KAREN OLSEN	11/30/2006	HOOD	2281	919	4259
TX	HOOD	TX2210120.23	RANDAL PAUL JORDAN	1/27/2007	HOOD	2281	838	4229
TX	HOOD	TX2210120.24	PATTI JORDAN ROOKS	1/27/2007	HOOD	2281	841	4230
TX	HOOD	TX2210120.25	PAULA JORDAN CHRISTOPHER	1/27/2007	HOOD	2281	844	4231
TX	HOOD	TX2210120.26	PAMELA JORDAN SPENCE	1/27/2007	HOOD	2281	847	4232
TX	HOOD	TX2210120.29	ROBERT LEE WILLIAMS	9/30/2006	HOOD	2244	887	18980
TX	HOOD	TX2210120.31	ELIZABETH A OESTREICH	9/28/2006	HOOD	2244	893	18982
TX	HOOD	TX2210120.32	ROBERT ALLEN RANEY	9/30/2006	HOOD	2244	896	18983
TX	HOOD	TX2210121.00	BROWN TERRY NEIL ET AL	9/5/2003	HOOD	1971	809	20290
TX	HOOD	TX2210123.01	ESTES GRADEN KYLE ET UX	12/5/2003	HOOD	1971	804	20288
TX	HOOD	TX2210123.02	CHENNAULT MAX B ET UX	1/7/2004	HOOD	1977	446	549
TX	HOOD	TX2210125.01	CLARENCE W VAUGHN JR ET UX	12/31/2003	HOOD	1976	889	391
TX	HOOD	TX2210125.02	RELIANCE STANDARD LIFE INS	4/28/2005	HOOD	2119	433	11969
TX	HOOD	TX2210125.03	ROBIN K SNIDER ET UX	5/19/2005	HOOD	2119	347	11941
TX	HOOD	TX2210125.04	MAX G HITT IND & INDEP EXE	2/10/2004	HOOD	2009	19	7848
TX	HOOD	TX2210125.05	EDWARD D LOWE	10/13/2006	HOOD	2270	28	1386
TX	HOOD	TX2210125.06	CAROLINE A BLACK	2/10/2004	HOOD	1991	143	3837
TX	HOOD	TX2210125.07	RICHARD L LANE ET UX	2/17/2004	HOOD	1987	585	3012
TX	HOOD	TX2210125.08	ANDREA L MINKE	3/3/2008	HOOD	2396	23	7514
TX	HOOD	TX2210125.09	ROY KINNARD ET UX	2/8/2008	HOOD	2392	190	6630
TX	HOOD	TX2210125.10	WOLF HOLLOW I LP	6/5/2008	HOOD	2433	277	16290
TX	HOOD	TX2210126.00	O P LEONARD JR INVEST CO	9/23/2003	HOOD	1956	619	16821
TX	HOOD	TX2210127.00	JAMES CHARLES L	11/22/2003	HOOD	1977	458	554
TX	HOOD	TX2210128.00	T & P PROPERTIES PART'SHIP	11/12/2003	HOOD	1977	460	555
TX	HOOD	TX2210129.00	CLEVELAND DAVID L ET UX	12/13/2003	HOOD	1977	454	552
TX	HOOD	TX2210132.00	HIGHTOWER LYNN S ET UX	11/24/2003	HOOD	1972	698	20514
TX	HOOD	TX2210133.00	JAMES CHARLES L ET AL	11/22/2003	HOOD	1977	456	553
TX	HOOD	TX2210134.01	O P LEONARD JR INVEST ETAL	9/23/2003	HOOD	1956	609	16817
TX	HOOD	TX2210134.02	LEONARD SCOUT PROPERTY	4/30/2006	HOOD	2196	534	8012
TX	HOOD	TX2210135.00	FORT WORTH REAL ESTATE INC	8/7/2001	HOOD	1788	153	14514
TX	HOOD	TX2210135.00	FORT WORTH REAL ESTATE INC	8/7/2001
TX	HOOD	TX2210136.00	LYNIE BELL KENNEDY	1/5/2004	HOOD	1977	452	551
TX	HOOD	TX2210137.00	GEE RALPH WENDELL ET UX	1/7/2004	HOOD	1977	434	545
TX	HOOD	TX2210138.00	JOHNNIE W ROLLINS ET UX	12/4/2003	HOOD	1977	440	546
TX	HOOD	TX2210138.00	JOHNNIE W ROLLINS ET UX	12/4/2003
TX	HOOD	TX2210139.01	KENNETH L PAYNE ET UX	1/14/2004	HOOD	1980	547	1332
TX	HOOD	TX2210139.02	SALLIE C SIMPSON	12/20/2006	HOOD	2289	219	5920
TX	HOOD	TX2210140.00	LINDON M STEWART ET UX	8/7/2001	HOOD	1929	309	10920
TX	HOOD	TX2210143.01	ALICE CASH NASH	1/20/2004	HOOD	1991	103	3823
TX	HOOD	TX2210143.02	MARY RHODES CHRISMAN	1/20/2004	HOOD	1991	99	3822
TX	HOOD	TX2210143.03	CHEYNE RONALD R	3/18/2004	HOOD	1996	320	5044
TX	HOOD	TX2210143.04	RON VAN HOFWEGEN ET UX	10/26/2004	HOOD	2055	732	18572
TX	HOOD	TX2210143.05	JAMES R PERRY & JUNE PERRY	5/1/2005	HOOD	2105	839	8867
TX	HOOD	TX2210143.06	RON INVESTMENTS LTD	12/8/2005	HOOD	2169	317	1152
TX	HOOD	TX2210143.07	RICHARD G HIBBELER ET UX	2/7/2006	HOOD	2180	982	4009
TX	HOOD	TX2210143.08	DERALYNN DEE DEMPSEY	5/15/2007	HOOD	2308	933	10638
TX	HOOD	TX2210143.09	JAMES W TRAVIS ET UX	7/14/2007	HOOD	2332	269	16058
TX	HOOD	TX2210143.10	MARK A PINSKA	6/14/2007	HOOD	2318	233	12814
TX	HOOD	TX2210143.12	DAVID SEARS ET UX	6/6/2007	HOOD	2318	245	12820
TX	HOOD	TX2210144.00	JUDITH A CHESBROUGH-SHAW	1/22/2004	HOOD	1984	628	2341
TX	HOOD	TX2210145.01	THORNTON LYNDA MACEACHIN	1/20/2004	HOOD	1983	442	2041
TX	HOOD	TX2210145.02	JACK MONROE RANDAL	1/20/2004	HOOD	1983	438	2040
TX	HOOD	TX2210145.03	STEVE C ELY ET UX	2/5/2007	HOOD	2281	899	4250
TX	HOOD	TX2210145.04	STEVE C ELY ET UX	2/5/2007	HOOD	2283	288	4630
TX	HOOD	TX2210145.05	STEVEN C WALT	2/8/2007	HOOD	2281	901	4251
TX	HOOD	TX2210145.06	RALPH L PURGET ET UX	2/12/2007	HOOD	2283	286	4629
TX	HOOD	TX2210145.07	JON A WHITE ET UX	2/5/2007	HOOD	2281	907	4254
TX	HOOD	TX2210145.08	JOAN FEY ET VIR	2/5/2007	HOOD	2281	905	4253
TX	HOOD	TX2210145.09	DELMAR L ULLOM ET UX	2/5/2007	HOOD	2281	903	4252
TX	HOOD	TX2210145.0A	JAMES W CULP	10/14/2008	HOOD	2449	14	20114
TX	HOOD	TX2210145.0B	J CULP INC	10/14/2008	HOOD	2442	874	18651
TX	HOOD	TX2210145.0C	JAYSON A CLUBB ET UX	6/1/2008	HOOD	2442	880	18654
TX	HOOD	TX2210145.0D	KEVIN W VANN JCD DD	10/14/2008	HOOD	2442	876	18652
TX	HOOD	TX2210145.0E	LYNDON L STROUD ET UX	5/10/2008	HOOD	2442	878	18653
TX	HOOD	TX2210145.0F	BETTY JO MCPHERSON & LINDA	10/20/2008	HOOD	2446	806	19627
TX	HOOD	TX2210145.0G	HAROLD E WARE ET UX	10/14/2008	HOOD	2442	898	18662
TX	HOOD	TX2210145.0H	KEVIN R CURRENT	11/12/2008	HOOD	2442	917	18669
TX	HOOD	TX2210145.0I	LEVI JACKSON ET UX	7/25/2008	HOOD	2442	919	18670
TX	HOOD	TX2210145.0J	DANNY MCGRAW JR ET UX	6/23/2008	HOOD	2446	780	19618
TX	HOOD	TX2210145.0K	ADAM DOUCET III ET UX	8/20/2008	HOOD	2463	530	3227
TX	HOOD	TX2210145.0M	ROBERT L STEELE JR ET UX	6/9/2008	HOOD	2449	38	20125
TX	HOOD	TX2210145.0N	MICHAEL SPENCER ET UX	6/10/2008	HOOD	2463	537	3230
TX	HOOD	TX2210145.0P	RON BAKER ET UX	3/30/2009	HOOD	2478	749	6556
TX	HOOD	TX2210145.0Q	CHARLES J CRAWFORD	3/30/2009	HOOD	2478	751	6557
TX	HOOD	TX2210145.0R	RYAN HUEBINGER ET UX	3/30/2009	HOOD	2474	151	5622
TX	HOOD	TX2210145.0S	JAMES C CROSBY ET UX	3/30/2009	HOOD	2481	882	7302
TX	HOOD	TX2210145.0T	CLESSIE HOLLOWAY ET UX	3/30/2009	HOOD	2481	880	7301
TX	HOOD	TX2210145.0U	CRAIG W GOSSARD ET UX	3/30/2009	HOOD	2481	888	7305
TX	HOOD	TX2210145.0V	DARRELL V ENDICOTT	3/30/2009	HOOD	2481	886	7304
TX	HOOD	TX2210145.0W	PATRICK A DANIEL ET UX	3/20/2009	HOOD	2481	878	7300
TX	HOOD	TX2210145.0X	TERESA L BRIGMAN ET VIR	3/30/2009	HOOD	2481	965	7332
TX	HOOD	TX2210145.0Y	KATHY SCOTT	3/30/2009	HOOD	2481	967	7333
TX	HOOD	TX2210145.0Z	MENG M LAM	6/8/2009	HOOD	2488	120	8724
TX	HOOD	TX2210145.10	RAYMOND F GADDY ET UX	2/5/2007	HOOD	2283	284	4628
TX	HOOD	TX2210145.11	JAIME R GARCIA ET UX	2/10/2007	HOOD	2281	895	4248
TX	HOOD	TX2210145.12	GAYLE MAX CALK ET UX	2/15/2007	HOOD	2281	897	4249
TX	HOOD	TX2210145.13	PAUL DIETRICH ET UX	2/6/2007	HOOD	2281	909	4255
TX	HOOD	TX2210145.14	VERNON L POE ET UX	2/10/2007	HOOD	2284	499	4829
TX	HOOD	TX2210145.15	ANTHONY E SHIFFLETT ET UX	2/10/2007	HOOD	2284	503	4831
TX	HOOD	TX2210145.16	WILLIAM GIBSON III ET UX	3/5/2007	HOOD	2289	245	5933
TX	HOOD	TX2210145.17	EUGENIA DARBONNE	3/7/2007	HOOD	2289	270	5940
TX	HOOD	TX2210145.18	RICKY D RHINE ET UX	2/26/2007	HOOD	2289	243	5932
TX	HOOD	TX2210145.19	JERRY D SMITH ET UX	3/14/2007	HOOD	2293	607	7013
TX	HOOD	TX2210145.1A	DAMON CUMBA ET UX	7/29/2009	HOOD	2501	462	11871
TX	HOOD	TX2210145.1B	KEESHA D ALLEN	7/30/2009	HOOD	2503	976	12530
TX	HOOD	TX2210145.1C	TIM W JUSTIS ET UX	10/16/2009	HOOD	2515	97	15280
TX	HOOD	TX2210145.1D	BERRY ALLEN HUFFMAN ET UX	12/15/2009	HOOD	2523	633	209
TX	HOOD	TX2210145.1E	LOUIS M BUSTOS	1/6/2010	HOOD	2524	924	560
TX	HOOD	TX2210145.1F	MARCUS A MALLOY ET UX	7/12/2011	HOOD			2011-0009299
TX	HOOD	TX2210145.1G	PAUL HYDE ET UX	8/25/2011	HOOD			2011-000996
TX	HOOD	TX2210145.20	CECIL N LILLARD ET UX	3/14/2007	HOOD	2293	605	7012
TX	HOOD	TX2210145.21	BILLY C SMITH ET UX	3/13/2007	HOOD	2293	621	7020
TX	HOOD	TX2210145.22	MICHAEL B BROWN ET UX	3/5/2007	HOOD	2293	619	7019
TX	HOOD	TX2210145.23	SCOTT R BERRY ET UX	3/7/2007	HOOD	2293	623	7021
TX	HOOD	TX2210145.24	GERALD T WILLIAMSON ET UX	3/19/2007	HOOD	2293	615	7017
TX	HOOD	TX2210145.25	GARY J PEDERSON ET UX	3/27/2007	HOOD	2293	609	7014
TX	HOOD	TX2210145.26	ELEANOR MCINTYRE ET VIR	3/14/2007	HOOD	2293	611	7015
TX	HOOD	TX2210145.27	RUSSELL VERNON ET UX	3/14/2007	HOOD	2293	613	7016
TX	HOOD	TX2210145.28	JAMES N BURKEEN JR ET UX	2/26/2007	HOOD	2293	617	7018
TX	HOOD	TX2210145.29	DAVID B CHANDLER ET UX	3/21/2007	HOOD	2298	691	8137
TX	HOOD	TX2210145.30	ANTHONY L LONG JR ET UX	3/28/2007	HOOD	2293	601	7010
TX	HOOD	TX2210145.31	JACKIE GATEWOOD	3/29/2007	HOOD	2293	603	7011
TX	HOOD	TX2210145.32	STANLEY J WINQUIST	3/14/2007	HOOD	2308	899	10626
TX	HOOD	TX2210145.33	YANCY D BRACKIN ET UX	2/7/2007	HOOD	2336	63	16951
TX	HOOD	TX2210145.34	MICHAEL J BROWN ET UX	8/30/2004	HOOD	2042	719	15454
TX	HOOD	TX2210145.35	RANDY L REMPEL ET UX	5/6/2008	HOOD	2405	711	9825
TX	HOOD	TX2210145.36	JAMES L WINQUIST ET UX	5/6/2008	HOOD	2405	713	9826
TX	HOOD	TX2210145.37	LORI J GRAHAM	3/14/2007	HOOD	2403	50	9193
TX	HOOD	TX2210145.38	RICHARD L KOCH ET UX	5/2/2008	HOOD	2405	715	9827
TX	HOOD	TX2210145.39	NICKY D MILSON ET UX	5/2/2008	HOOD	2405	684	9813
TX	HOOD	TX2210145.40	JAMES R SZENASY ET UX	5/6/2008	HOOD	2405	686	9814
TX	HOOD	TX2210145.41	GILBERT N HARRISON ET UX	5/2/2008	HOOD	2408	496	10428
TX	HOOD	TX2210145.42	MELISSA ANNE NADASON	5/6/2008	HOOD	2414	243	11735
TX	HOOD	TX2210145.43	ROBERT B MCGEE ET UX	5/6/2008	HOOD	2405	688	9815
TX	HOOD	TX2210145.44	CASEY WALLACE ET UX	5/6/2008	HOOD	2405	678	9810
TX	HOOD	TX2210145.45	TIMOTHY HILTON ET UX	5/16/2008	HOOD	2405	682	9812
TX	HOOD	TX2210145.46	LEONARD J BANKFORD ET UX	5/16/2008	HOOD	2405	690	9816
TX	HOOD	TX2210145.47	JACK D FALLIN ET UX	5/6/2008	HOOD	2414	237	11732
TX	HOOD	TX2210145.48	GENE HUGHES ET UX	5/6/2008	HOOD	2414	235	11731
TX	HOOD	TX2210145.49	MELISSA J WHITTET	5/27/2008	HOOD	2414	245	11736
TX	HOOD	TX2210145.50	ROBERT L SCHNICK ET UX	6/10/2008	HOOD	2414	253	11740
TX	HOOD	TX2210145.51	DOYLE A MILLER ET UX	6/10/2008	HOOD	2414	255	11741
TX	HOOD	TX2210145.52	JUDITH LYNN YOUNG	6/10/2008	HOOD	2414	222	11725
TX	HOOD	TX2210145.53	RONALD R NEWSOM ET UX	6/1/2008	HOOD	2414	257	11742
TX	HOOD	TX2210145.54	KEVIN E VOIGT ET UX	6/10/2008	HOOD	2414	293	11759
TX	HOOD	TX2210145.55	LAYNE S LADNER ET UX	6/10/2008	HOOD	2414	295	11760
TX	HOOD	TX2210145.56	JOHN R COX ET UX	6/23/2008	HOOD	2414	297	11761
TX	HOOD	TX2210145.57	LINDA HARTE	6/1/2008	HOOD	2419	138	12935
TX	HOOD	TX2210145.58	JOSEPH S GRISHAM ET UX	6/23/2008	HOOD	2414	287	11756
TX	HOOD	TX2210145.59	STUART B SMITH ET UX	6/23/2008	HOOD	2414	272	11749
TX	HOOD	TX2210145.60	WILLIAM GARY EMMETT ET UX	7/1/2008	HOOD	2414	277	11751
TX	HOOD	TX2210145.61	CHARLES BANDEMER ET UX	6/10/2008	HOOD	2419	171	12950
TX	HOOD	TX2210145.62	GLORIA FREDRICK ET AL	6/10/2008	HOOD	2419	144	12938
TX	HOOD	TX2210145.63	ROBERT I DAVIS ET UX	6/23/2008	HOOD	2419	148	12940
TX	HOOD	TX2210145.64	JERRY GEORGE ET UX	6/16/2008	HOOD	2419	146	12939
TX	HOOD	TX2210145.65	ZACKARY ERWIN ET UX	6/23/2008	HOOD	2419	150	12941
TX	HOOD	TX2210145.66	JEANA K LOCKE	6/23/2008	HOOD	2419	140	12936
TX	HOOD	TX2210145.67	TODD OPPERMANN ET UX	6/23/2008	HOOD	2429	910	15444
TX	HOOD	TX2210145.68	PRICE MIDDLEBROOK III ETUX	7/1/2008	HOOD	2419	161	12945
TX	HOOD	TX2210145.69	DARRELL D HARRISON ET UX	6/16/2008	HOOD	2419	163	12946
TX	HOOD	TX2210145.70	JEROME R YOUNG	5/16/2008	HOOD	2433	268	16286
TX	HOOD	TX2210145.71	RONALD LEE BERRYMAN ET UX	5/27/2008	HOOD	2433	322	16309
TX	HOOD	TX2210145.72	JACK F WORKMAN ET UX	7/15/2008	HOOD	2429	906	15442
TX	HOOD	TX2210145.73	ROBERT BERRY ET UX	6/16/2008	HOOD	2429	908	15443
TX	HOOD	TX2210145.74	BARRY N SMITH ET UX	5/6/2008	HOOD	2429	916	15447
TX	HOOD	TX2210145.75	FLOYD E COLLINS III ET UX	6/23/2008	HOOD	2429	932	15455
TX	HOOD	TX2210145.76	BOBBYE R PETTY	7/1/2008	HOOD	2423	150	13939
TX	HOOD	TX2210145.77	DIXON 1982 TRUST	7/15/2008	HOOD	2423	155	13942
TX	HOOD	TX2210145.78	KEVIN ROBERTS ET UX	7/15/2008	HOOD	2429	928	15453
TX	HOOD	TX2210145.79	THEARON W LANDRUM ET UX	7/23/2008	HOOD	2429	926	15452
TX	HOOD	TX2210145.80	G MICHAEL DIXON ET UX	6/23/2008	HOOD	2429	866	15422
TX	HOOD	TX2210145.81	TERRY DARRELL MAYO ET UX	7/15/2008	HOOD	2429	914	15446
TX	HOOD	TX2210145.82	DIANNE L FORD	5/6/2008	HOOD	2429	912	15445
TX	HOOD	TX2210145.83	EARL GILLUM JR ET UX	7/15/2008	HOOD	2429	918	15448
TX	HOOD	TX2210145.84	EARL COPPERSMITH ET UX	8/15/2008	HOOD	2429	922	15450
TX	HOOD	TX2210145.85	MARK G KERTZ ET UX	7/25/2008	HOOD	2429	920	15449
TX	HOOD	TX2210145.86	JOHN W PETTY II ET UX	6/16/2008	HOOD	2429	924	15451
TX	HOOD	TX2210145.87	AMY BELL	8/20/2008	HOOD	2433	300	16300
TX	HOOD	TX2210145.88	JOHN W PATTEN ET UX	8/12/2008	HOOD	2429	886	15432
TX	HOOD	TX2210145.89	DALE L SAATHOFF	6/23/2008	HOOD	2433	285	16293
TX	HOOD	TX2210145.90	LONNIE M FOX ET UX	7/25/2008	HOOD	2433	310	16304
TX	HOOD	TX2210145.91	DONALD R HOLMES ET UX	7/1/2008	HOOD	2433	291	16296
TX	HOOD	TX2210145.92	JOHNNY V STANDRIDGE ET UX	8/20/2008	HOOD	2434	976	16751
TX	HOOD	TX2210145.93	ROGER ENLOW ET UX	8/25/2008	HOOD	2437	269	17311
TX	HOOD	TX2210145.94	KAREN Z BITNAR INDIV & AIF	5/6/2008	HOOD	2437	276	17314
TX	HOOD	TX2210145.95	ERIC M BLEVINS ET UX	8/12/2008	HOOD	2449	4	20110
TX	HOOD	TX2210145.96	MARLEY INVESTMENTS LP	7/10/2008	HOOD	2437	274	17313
TX	HOOD	TX2210145.97	ACTON MUNICIPAL UTILITY	9/1/2008	HOOD	2442	847	18640
TX	HOOD	TX2210145.98	GEORGE W HAYDEN JR ET UX	9/4/2008	HOOD	2449	22	20118
TX	HOOD	TX2210146.00	PURSELLEY MARIA M	2/19/2004	HOOD	1991	128	3831
TX	HOOD	TX2210147.01	KING RAYMOND ET UX	2/10/2004	HOOD	1991	134	3833
TX	HOOD	TX2210147.02	DONNA E STOKER ET VIR	8/11/2004	HOOD	2038	255	14365
TX	HOOD	TX2210147.03	M G DURANT ET UX	8/14/2004	HOOD	2038	253	14364
TX	HOOD	TX2210147.04	DONALD L MOLINARI ET UX	8/4/2004	HOOD	2038	264	14369
TX	HOOD	TX2210147.05	RICHIE HAUGHT ET UX	8/25/2004	HOOD	2038	251	14363
TX	HOOD	TX2210147.06	M G DURANT ET UX	8/28/2004	HOOD	2038	249	14362
TX	HOOD	TX2210147.07	ALLEN ROBERT TACQUARD ETUX	9/1/2004	HOOD	2042	715	15452
TX	HOOD	TX2210147.08	EULA B GREEN	9/1/2004	HOOD	2042	709	15449
TX	HOOD	TX2210147.09	CAROL D HULSEY ET VIR	8/12/2004	HOOD	2042	706	15448
TX	HOOD	TX2210147.10	JAMES LYNCH ET UX	8/20/2004	HOOD	2111	522	10125
TX	HOOD	TX2210149.00	LEONARD HEATHINGTON	2/6/2004	HOOD	1984	623	2339
TX	HOOD	TX2210149.00	LEONARD HEATHINGTON	2/6/2004
TX	HOOD	TX2210150.00	AMYETT TIMOTHY ET UX	2/2/2004	HOOD	1984	618	2337
TX	HOOD	TX2210151.00	PARRISH WILLIAM C ET UX	12/31/2003	HOOD	1980	541	1330
TX	HOOD AND JOHNSON	TX2210152.01	PALLMEYER WYNONIA IND/TRE	2/23/2004	HOOD	1987	596	3016
TX	HOOD AND JOHNSON	TX2210152.01	PALLMEYER WYNONIA IND/TRE	2/23/2004
TX	HOOD AND JOHNSON	TX2210152.01	PALLMEYER WYNONIA IND/TRE	2/23/2004
TX	HOOD AND JOHNSON	TX2210152.01	PALLMEYER WYNONIA IND/TRE	2/23/2004
TX	HOOD AND JOHNSON	TX2210152.02	ROBERT RASH COPE	3/4/2005	HOOD	2087	243	4504
TX	HOOD AND JOHNSON	TX2210152.02	ROBERT RASH COPE	3/4/2005	JOHNSON	3506	354	11432
TX	HOOD AND JOHNSON	TX2210152.03	MICHAEL WINBURY SPILLER	3/10/2005	HOOD	2087	246	4505
TX	HOOD AND JOHNSON	TX2210152.03	MICHAEL WINBURY SPILLER	3/10/2005	JOHNSON	3506	358	11433
TX	HOOD	TX2210154.01	DAVID HARRIS ET UX	2/23/2004	HOOD	1987	588	3013
TX	HOOD	TX2210154.02	JAMES G WALSH TRUSTEE	3/23/2004	HOOD	2000	817	6152
TX	HOOD	TX2210154.03	JAMES G WALSH TRUSTEE	4/20/2004	HOOD	2005	81	7034
TX	HOOD	TX2210155.00	BILLY GENE ARMS ET UX	2/18/2004	HOOD	1987	578	3009
TX	HOOD	TX2210156.00	RODRIGUEZ MANUEL ET UX	2/24/2004	HOOD	1987	576	3008
TX	HOOD	TX2210158.00	SULLIVAN JOHN M	2/28/2004	HOOD	1991	139	3835
TX	HOOD	TX2210159.00	PARAMORE MICHAEL G ET UX	3/3/2004	HOOD	1991	141	3836
TX	HOOD	TX2210160.00	SHEFFIELD LARRY E ET UX	2/16/2004	HOOD	1991	115	3827
TX	HOOD	TX2210165.00	TEMPLE ROBERT D ET UX	2/26/2004	HOOD	1991	110	3825
TX	HOOD	TX2210166.00	CULLEN LEE CRISP ET UX	2/24/2004	HOOD	1996	293	5032
TX	HOOD	TX2210168.00	ISENBERG LEWIS H ET UX	3/5/2004	HOOD	1996	318	5043
TX	HOOD	TX2210170.00	DALY JAMES P ET UX	3/8/2004	HOOD	1996	310	5039
TX	HOOD	TX2210171.00	WHITE BRET A ET UX	3/4/2004	HOOD	1996	283	5027
TX	HOOD	TX2210172.00	CARMICHAEL FAMILY TRUST	3/26/2004	HOOD	1996	279	5025
TX	HOOD	TX2210173.00	MILSTEAD VERLLER	3/27/2004	HOOD	1996	281	5026
TX	HOOD	TX2210174.00	BENNETT JEANNE CATHERINE	3/26/2004	HOOD	1996	312	5040
TX	HOOD	TX2210175.00	TROY E MILSTEAD	3/27/2004	HOOD	1996	287	5029
TX	HOOD	TX2210176.00	RICHARD F FURR ET UX	3/26/2004	HOOD	1996	289	5030
TX	HOOD	TX2210178.00	DALY TIMOTHY ET UX	3/24/2004	HOOD	1996	276	5024
TX	HOOD	TX2210179.00	WALSH JAMES G INDIV/EXE	3/23/2004	HOOD	1996	299	5035
TX	HOOD	TX2210180.00	JAMES G WALSH TRUSTEE	3/23/2004	HOOD	1996	301	5036
TX	HOOD	TX2210181.00	WALSH JAMES G TRUSTEE	3/23/2004	HOOD	1996	303	5037
TX	HOOD	TX2210183.00	WHEELER WILLIAM ET UX	3/27/2004	HOOD	2000	808	6149
TX	HOOD	TX2210184.00	SONDERER CY S ET UX	3/27/2004	HOOD	2000	806	6148
TX	HOOD	TX2210187.00	HELEN ANDERSON	4/6/2004	HOOD	2005	83	7035
TX	HOOD	TX2210188.00	ROPER PHILLIP D ET UX	3/31/2004	HOOD	2000	801	6146
TX	HOOD	TX2210189.00	JACKSON JR TOMMY WAYNE	4/10/2004	HOOD	2000	804	6147
TX	HOOD	TX2210191.00	MOORE GWENDOLYN C	4/10/2004	HOOD	2005	74	7031
TX	HOOD	TX2210192.00	MOORE III GE0RGE M	3/31/2004	HOOD	2005	76	7032
TX	HOOD	TX2210193.00	DOWNING KEVIN S ET UX	4/13/2004	HOOD	2005	87	7036
TX	HOOD	TX2210195.00	MARTIN NOEL DAVID ET AL	4/16/2004	HOOD	2005	78	7033
TX	HOOD	TX2210196.00	KANAFSKY ROCHANA CASH	4/28/2004	HOOD	2009	13	7845
TX	HOOD	TX2210197.00	MCKENZIE RUFUS P	4/30/2004	HOOD	2009	17	7847
TX	HOOD	TX2210198.00	MCKENZIE RUFUS P	4/30/2004	HOOD	2009	15	7846
TX	HOOD	TX2210199.01	E LYNDA FILLER	5/10/2004	HOOD	2009	3	7841
TX	HOOD	TX2210199.02	RAYMOND S HIGGINS	7/10/2007	HOOD	2324	651	14321
TX	HOOD	TX2210201.01	MCKENZIE RUFUS P	4/30/2004	HOOD	2013	602	8692
TX	HOOD	TX2210201.02	HARRIETT ROBERTS	9/1/2006	HOOD	2269	989	1370
TX	HOOD	TX2210202.00	BOHN DENNIS ET UX	4/16/2004	HOOD	2009	9	7843
TX	HOOD	TX2210203.00	CROWE IV WILLIAM H ET UX	5/6/2004	HOOD	2013	598	8690
TX	HOOD	TX2210204.00	MARLOWE JAMES A	5/12/2004	HOOD	2013	600	8691
TX	HOOD	TX2210207.00	HAZLE THOMAS CALVIN	5/5/2004	HOOD	2013	596	8689
TX	HOOD	TX2210208.99	JOE D. EVANS	5/27/2004	HOOD	2012	124	8393
TX	HOOD	TX2210209.99	VIRGINIA FERN MARTIN	5/27/2004	HOOD	2012	129	8396
TX	HOOD	TX2210210.00	EULA ANN MARTIN	5/19/2004	HOOD	2013	594	8688
TX	HOOD	TX2210211.01	JACKIE D ABLES	4/27/2004	HOOD	2013	588	8686
TX	HOOD	TX2210211.02	JAMES G WALSH TRUSTEE	3/7/2007	HOOD	2293	560	6993
TX	HOOD	TX2210212.00	PAUL LUTHER HIGGINS / VLB	5/13/2004	HOOD	2021	370	10439
TX	HOOD	TX2210213.01	ALICE CASH NASH	5/27/2004	HOOD	2013	567	8680
TX	HOOD	TX2210213.02	MARY RHODES CHRISMAN	5/28/2004	HOOD	2013	565	8679
TX	HOOD	TX2210213.03	CLAYTON ROBSHAW ET UX	6/11/2007	HOOD	2318	255	12825
TX	HOOD	TX2210213.04	EUNICE L ALLEN TACKETT	6/1/2004	HOOD	2021	411	10450
TX	HOOD	TX2210214.00	RICHARD JOSEPH SABO ET UX	4/28/2004	HOOD	2013	582	8684
TX	HOOD	TX2210215.00	GARY L COX & DEBRA K COX	6/7/2004	HOOD	2021	409	10449
TX	HOOD	TX2210217.01	JAMES G WALSH TRUSTEE	6/3/2004	HOOD	2021	407	10448
TX	HOOD	TX2210217.02	GRACE ELIZABETH JOHNSON	2/26/2007	HOOD	2284	515	4836
TX	HOOD	TX2210217.03	RAY E MASSIE ET UX	2/26/2007	HOOD	2281	874	4242
TX	HOOD	TX2210220.00	KEVIN GROVE & MARY GROVE	6/25/2004	HOOD	2021	1002	10555
TX	HOOD	TX2210221.00	RICHARD J HOLEMAN ET UX	6/25/2004	HOOD	2021	347	10430
TX	HOOD	TX2210222.00	MORRIS HESSELTINE ET UX	6/25/2004	HOOD	2021	345	10429
TX	HOOD	TX2210223.00	JAMES LAND & KATHY LAND	6/25/2004	HOOD	2021	343	10428
TX	HOOD	TX2210225.00	BYRON D KING ET UX	6/14/2004	HOOD	2021	1000	10554
TX	HOOD	TX2210226.00	MARTHA DALENE KING	6/24/2004	HOOD	2021	368	10438
TX	HOOD	TX2210227.00	L TERRY GREEN ET UX	6/28/2004	HOOD	2022	916	10785`
TX	HOOD	TX2210229.00	C B COX JR & BEVERLY C COX	7/7/2004	HOOD	2028	298	12078
TX	HOOD	TX2210230.00	JAMES R MAYES	5/14/2004	HOOD	2028	288	12075
TX	HOOD	TX2210231.00	DALE ALLEN SPARKS	6/6/2004	HOOD	2028	286	12074
TX	HOOD	TX2210232.00	K A SPARKS & KAREN SPARKS	6/9/2004	HOOD	2028	284	12073
TX	HOOD	TX2210233.00	RALPH WENDELL GEE	7/8/2004	HOOD	2028	282	12072
TX	HOOD	TX2210241.00	CHRISTINE WYATT	7/8/2004	HOOD	2059	775	19472
TX	HOOD	TX2210242.00	ERNEST D BICKLE ET UX	7/13/2004	HOOD	2028	269	12067
TX	HOOD	TX2210243.01	BYRON L CALLAHAN / VLB	6/24/2004	HOOD	2051	382	17563
TX	HOOD	TX2210243.02	MARVIN COLLINS	7/7/2004	HOOD	2032	302	12922
TX	HOOD	TX2210243.03	JAKE COOK	7/26/2004	HOOD	2038	262	14368
TX	HOOD	TX2210243.04	WILLIAM N LUEBBEHUSEN ETUX	12/10/2004	HOOD	2068	542	291
TX	HOOD	TX2210243.05	PHILLIP E LUEBBEHUSEN	12/10/2004	HOOD	2068	562	298
TX	HOOD	TX2210243.06	LEO A LUEBBEHUSEN	11/14/2007	HOOD	2356	737	21740
TX	HOOD	TX2210243.07	STEPHEN LUEBBEHUSEN ET UX	11/14/2007	HOOD	2356	739	21741
TX	HOOD	TX2210247.00	HOWARD F CHEEK ET UX	8/28/2004	HOOD	2042	727	15458
TX	HOOD	TX2210248.00	CAROLYN GODWIN	9/7/2004	HOOD	2042	725	15457
TX	HOOD	TX2210249.00	BILL C JACKSON ET UX	8/30/2004	HOOD	2042	730	15459
TX	HOOD	TX2210250.01	GEORGE DEE MATHIS	8/30/2004	HOOD	2042	736	15461
TX	HOOD	TX2210250.02	DOLORES HOLDEN	9/10/2004	HOOD	2042	741	15463
TX	HOOD	TX2210250.03	RODGER W BOWEN ET UX	10/17/2004	HOOD	2055	726	18570
TX	HOOD	TX2210251.01	BRYAN KEITH PAYNE	7/29/2004	HOOD	2042	733	15460
TX	HOOD	TX2210252.00	GLENDA M CAMPBELL	9/10/2004	HOOD	2042	711	15450
TX	HOOD	TX2210253.00	LEONARD ENTERPRISES INC	9/1/2004	HOOD	2042	738	15462
TX	HOOD	TX2210254.01	JACK L MAYFIELD	9/10/2004	HOOD	2042	713	15451
TX	HOOD	TX2210254.02	DAVID A SPRADLIN ET UX	1/28/2005	HOOD	2082	52	3427
TX	HOOD	TX2210255.00	R J SMELLEY ET AL	7/27/2001	HOOD	1767	211	9807
TX	HOOD	TX2210256.00	KUGGA MONCRIEF	9/14/2004	HOOD	2042	723	15456
TX	HOOD	TX2210257.00	RANDALL M REAVES ET UX	9/10/2004	HOOD	2042	721	15455
TX	HOOD	TX2210259.00	RALPH WENDELL GEE ET UX	9/14/2004	HOOD	2042	717	15453
TX	HOOD	TX2210267.00	WILLIAM L KING ET UX	9/7/2004	HOOD	2051	380	17562
TX	HOOD	TX2210268.00	MILL STREAM INVESTMENT PRT	9/29/2004	HOOD	2051	378	17561
TX	HOOD	TX2210269.00	JAMES FAMILY PARNERSHIP	9/29/2004	HOOD	2051	374	17559
TX	HOOD	TX2210270.00	WINSTON A SPARKS	9/22/2004	HOOD	2051	363	17554
TX	HOOD	TX2210271.00	RICHARD A CANANN ET AL	9/15/2004	HOOD	2051	367	17556
TX	HOOD	TX2210272.00	TERRI L GARNER REV TRUST	10/1/2004	HOOD	2051	370	17557
TX	HOOD	TX2210273.00	S B BEASLEY ET UX	9/28/2004	HOOD	2059	777	19473
TX	HOOD	TX2210275.00	MICHAEL CAMPBELL ET UX	10/9/2004	HOOD	2143	530	17409
TX	HOOD	TX2210276.20	JACKIE LYNN HAWKINS ET UX	9/6/2011	HOOD			2011-0010835
TX	HOOD	TX2210276.22	FRANCES BANDY ET VIR	9/26/2011	HOOD			2011-0010837
TX	HOOD	TX2210276.26	NATHAN HAWKINS ET UX	9/6/2011	HOOD			2011-0011936
TX	HOOD	TX2210276.27	RUSSELL W HAWKINS	10/7/2014	HOOD			2014-0011173
TX	HOOD	TX2210276.28	JERRY M MARTIN ET UX	10/13/2014	HOOD			2014-0011174
TX	HOOD	TX2210276.29	ROBERT RHETT RHODES ET UX	10/18/2014	HOOD			2014-0012091
TX	HOOD	TX2210276.30	DONNA G STEPHENS ET VIR	9/15/2014	HOOD			2014-0011178
TX	HOOD	TX2210276.31	CARRIE DELAINE RHODES	10/18/2014	HOOD			2014-0012090
TX	HOOD	TX2210276.32	JAMES ORAN RHODES	10/18/2014	HOOD			2015-0000670
TX	HOOD	TX2210277.00	GILBERT HENSLEE ET UX	10/25/2004	HOOD	2059	780	19474
TX	HOOD	TX2210278.00	SUNNYE L BURT	10/5/2004	HOOD	2051	372	17558
TX	HOOD	TX2210279.00	ISABEL FORD SCOTT EST ETAL	10/13/2004	HOOD	2051	350	17551
TX	HOOD	TX2210281.00	JASON SCOTT WORTHEN ET UX	10/18/2004	HOOD	2059	766	19469
TX	HOOD	TX2210285.00	RON GREENTHALER ET EX	10/20/2004	HOOD	2055	742	18756
TX	HOOD	TX2210287.00	RICKEY CURLEE ET UX	11/1/2004	HOOD	2052	979	17905
TX	HOOD	TX2210288.00	STEPHEN W WILLIAMS ET UX	10/19/2004	HOOD	2059	769	19470
TX	HOOD	TX2210290.01	PAYTE INVESTMENTS LTD	12/13/2004	HOOD	2071	276	984
TX	HOOD	TX2210290.15	SAM L SHIPLEY ET UX	5/11/2005	HOOD	2106	747	9115
TX	HOOD	TX2210290.16	WYNONIA PALLMEYER ESTATE	4/25/2005	HOOD	2119	345	11940
TX	HOOD	TX2210290.46	JAMES L PALMER	8/12/2007	HOOD	2370	497	1576
TX	HOOD	TX2210293.00	JAMES ALAN EASLEY ET UX	12/6/2004	HOOD	2064	245	20506
TX	HOOD	TX2210296.00	JERRY D DAWSON	12/10/2004	HOOD	2068	535	289
TX	HOOD	TX2210298.00	KRISTIE ANN HOOVER DAVIS	12/30/2004	HOOD	2073	179	1455
TX	HOOD	TX2210299.00	HENRY E HOOVER ET UX	12/30/2004	HOOD	2073	177	1454
TX	HOOD	TX2210301.00	HELEN JANE VAUGHN	10/12/2004	HOOD	2068	560	297
TX	HOOD	TX2210302.00	ALICE A CHASE	10/12/2004	HOOD	2068	558	296
TX	HOOD	TX2210303.00	BETTY L MCCREIGHT	10/12/2004	HOOD	2068	552	294
TX	HOOD	TX2210305.00	ROBERT D KILLION JR ET UX	10/21/2004	HOOD	2073	193	1461
TX	HOOD	TX2210308.01	DONALD DIRKS ET UX	12/8/2004	HOOD	2071	285	986
TX	HOOD	TX2210310.00	LARRY G COTTLE ET UX	12/15/2004	HOOD	2073	183	1457
TX	HOOD	TX2210317.00	DICK BRUTON	1/22/2005	HOOD	2079	177	2809
TX	HOOD	TX2210319.00	ACTON CEMETERY INC	2/28/2005	HOOD	2093	23	5849
TX	HOOD	TX2210319.00	ACTON CEMETERY INC	2/28/2005
TX	HOOD	TX2210320.00	C K & SARAH CLEVELAND TR	2/28/2005	HOOD	2093	26	5850
TX	HOOD	TX2210322.00	LESLIE GERALD LEAKE ET UX	2/24/2005	HOOD	2083	249	3699
TX	HOOD	TX2210323.10	ACTON MUNICIPAL UTILITY DI	10/28/2008	HOOD	2442	952	18681
TX	HOOD	TX2210323.10	ACTON MUNICIPAL UTILITY DI	10/28/2008
TX	HOOD	TX2210323.11	FAIRRIS NORTHWEST LTD	10/3/2008	HOOD	2442	911	18667
TX	HOOD	TX2210323.16	LORIE K HOLLOWAY	2/7/2009	HOOD	2463	516	3222
TX	HOOD	TX2210323.21	JIMMY D GLENN	3/8/2012	HOOD			2012-0003123
TX	HOOD	TX2210323.22	RAMONA ANN ELLIOTT	2/2/2012	HOOD			2012-0004112
TX	HOOD	TX2210323.23	BARY JAY NUSZ	2/2/2012	HOOD			2012-0004113
TX	HOOD	TX2210323.24	JACQUE LAWANA SELVIDGE	2/2/2012	HOOD			2012-0004278
TX	HOOD	TX2210323.25	LUELLA ADELL SPRUILL	2/2/2012	HOOD			2012-0004590
TX	HOOD	TX2210323.29	THOMAS EDWARD WALLS	2/2/2012	HOOD			2012-0005489
TX	HOOD	TX2210323.30	LILLIE MAURICE ROGERS	2/2/2012	HOOD			2012-0005490
TX	HOOD	TX2210323.31	LINDA SUE WILL	2/2/2012	HOOD			2012-0005485
TX	HOOD	TX2210323.33	SHALMIR LUKICH	1/23/2015	HOOD			2015-0002335
TX	HOOD	TX2210330.00	GENERATIONS CHURCH	4/18/2005	HOOD	2105	835	8866
TX	HOOD	TX2210338.00	MARY F SHARPE ET AL	6/15/2005	HOOD	2121	241	12349
TX	HOOD	TX2210339.00	KEVIN FORTNEY ET UX	7/20/2005	HOOD	2121	238	12348
TX	HOOD	TX2210340.00	WILLIAM M MARTENSEN	7/26/2005	HOOD	2128	67	13817
TX	HOOD	TX2210343.00	GARY M HIBBS ET UX	8/12/2005	HOOD	2134	65	15157
TX	HOOD	TX2210344.01	KELVIN AARON WRIGHT	9/5/2005	HOOD	2139	299	16421
TX	HOOD	TX2210344.02	NARISSA WRIGHT BARRETT	9/5/2005	HOOD	2139	303	16422
TX	HOOD	TX2210344.03	CYNTHIA S THOMAS ET VIR	5/25/2006	HOOD	2211	506	11234
TX	HOOD	TX2210344.04	JANET M DIXON ET VIR	5/25/2006	HOOD	2212	679	11505
TX	HOOD	TX2210344.05	LEE ANNE WILLIAMS	5/25/2006	HOOD	2212	683	11507
TX	HOOD	TX2210344.06	JAMES WASINGER	5/25/2006	HOOD	2212	49	11366
TX	HOOD	TX2210344.07	RICHARD WASINGER ET UX	5/25/2006	HOOD	2212	47	11365
TX	HOOD	TX2210346.00	ROBT MOORE/ CURTIS HARRIS	7/20/2005	HOOD	2139	307	16423
TX	HOOD	TX2210352.00	JUAN B ZAMUDIO ET UX	9/16/2005	HOOD	2145	648	17924
TX	HOOD	TX2210352.00	JUAN B ZAMUDIO ET UX	9/16/2005
TX	HOOD	TX2210353.00	BILLY LAIL ET UX	9/7/2005	HOOD	2141	626	16955
TX	HOOD	TX2210356.00	ZETA C MARTIN, IND AND TR	9/20/2005	HOOD	2145	651	17925
TX	HOOD	TX2210357.00	CARMEN NELL ANDREWS ET AL	9/17/2005	HOOD	2149	52	18644
TX	HOOD	TX2210357.00	CARMEN NELL ANDREWS ET AL	9/17/2005
TX	HOOD	TX2210358.00	RICKEY CARL ANDREWS ET UX	9/17/2005	HOOD	2149	30	18637
TX	HOOD	TX2210359.00	MELMA JEAN LINTHICUM	9/30/2005	HOOD	2149	55	18645
TX	HOOD	TX2210361.00	TOM CRUM ET UX	8/8/2005	HOOD	2149	57	18646
TX	HOOD	TX2210363.00	3925 PARTNERS, LTD	10/11/2005	HOOD	2249	324	20012
TX	HOOD	TX2210367.01	TOM DURANT ET UX	10/11/2005	HOOD	2155	868	20251
TX	HOOD	TX2210367.02	EDMOND DAVIS WOODARD ET UX	10/5/2005	HOOD	2158	213	20846
TX	HOOD	TX2210367.03	CHARLES R HOFFMAN SR	11/7/2008	HOOD	2440	539	18106
TX	HOOD	TX2210367.04	NANCY CLARKE STOGNER	3/16/2009	HOOD	2472	643	5246
TX	HOOD	TX2210367.05	JOHN H CLARKE	3/16/2009	HOOD	2472	649	5249
TX	HOOD	TX2210367.06	BOBBIE HELEN CLARKE	3/16/2009	HOOD	2472	647	5248
TX	HOOD	TX2210367.07	AUSTIN RAY CLARKE	3/16/2009	HOOD	2472	645	5247
TX	HOOD	TX2210367.08	ROBERT FRANKLIN STEPHENSON	3/7/2009	HOOD	2471	802	5035
TX	HOOD	TX2210367.08	ROBERT FRANKLIN STEPHENSON	3/7/2009
TX	HOOD	TX2210367.09	JON LINDSEY STEPHENSON	3/7/2009	HOOD	2471	804	5036
TX	HOOD	TX2210367.09	JON LINDSEY STEPHENSON	3/7/2009
TX	HOOD	TX2210367.10	JAMES ALLEN STEPHENSON	3/7/2009	HOOD	2471	800	5034
TX	HOOD	TX2210367.10	JAMES ALLEN STEPHENSON	3/7/2009
TX	HOOD	TX2210368.01	DORIS JEAN FRANCISCO	9/26/2005	HOOD	2149	28	18636
TX	HOOD	TX2210368.02	DARRELL WARD JR ET UX	1/25/2006	HOOD	2173	313	2178
TX	HOOD	TX2210370.00	GEORGIA M W DAVENPORT	9/9/2005	HOOD	2155	866	20250
TX	HOOD	TX2210371.00	J E WINTERS FAM PART LTD	9/9/2005	HOOD	2155	877	20255
TX	HOOD	TX2210372.01	PAMELA KAY CASH	9/26/2005	HOOD	2155	872	20253
TX	HOOD	TX2210372.02	CHRISTOPHER C CASH JR	9/26/2005	HOOD	2155	870	20252
TX	HOOD	TX2210377.00	DAMRON WAYLAND REECE ET UX	9/18/2003	HOOD	1956	614	16819
TX	HOOD	TX2210378.00	WILLIAM F HARRIS ET UX	11/21/2005	HOOD	2158	209	20845
TX	HOOD	TX2210378.00	WILLIAM F HARRIS ET UX	11/21/2005
TX	HOOD	TX2210382.01	JOHN S RAINES	11/29/2005	HOOD	2161	515	21450
TX	HOOD	TX2210382.02	SIGNATURE CABINETRY & CUST	12/26/2005	HOOD	2173	319	2180
TX	HOOD	TX2210384.00	JACK L MARTIN SR ET UX	6/30/2004	HOOD	2031	952	12843
TX	HOOD	TX2210385.00	KENNETH L MASSEY	8/9/2004	HOOD	2053	524	18032
TX	HOOD	TX2210392.00	SU LIN HODGES ET VIR	11/8/2005	HOOD	2173	322	2181
TX	HOOD	TX2210393.00	DEBBIE THOMPSON ET VIR	11/24/2005	HOOD	2173	315	2179
TX	HOOD	TX2210398.00	GERALD L FINN	3/2/2006	HOOD	2186	141	5361
TX	HOOD	TX2210400.00	TERRY K FLEMING ET UX	1/31/2006	HOOD	2186	146	5363
TX	HOOD	TX2210403.00	BRIAN S HORTON	3/15/2006	HOOD	2186	132	5358
TX	HOOD	TX2210404.00	PATSY BEDSOLE	3/8/2006	HOOD	2191	289	6517
TX	HOOD	TX2210405.00	TERRY MORALES	4/26/2006	HOOD	2211	517	11237
TX	HOOD	TX2210407.01	JASON BRITT ET UX	4/18/2006	HOOD	2201	307	9141
TX	HOOD	TX2210407.02	GARRY Z LUKER	4/18/2006	HOOD	2201	309	9142
TX	HOOD	TX2210408.03	ALLAN A STRIEGLER	4/19/2006	HOOD	2211	484	11225
TX	HOOD	TX2210408.04	JOHN HOWARD STRIEGLER	4/19/2006	HOOD	2218	485	12882
TX	HOOD	TX2210408.04	JOHN HOWARD STRIEGLER	4/19/2006
TX	HOOD	TX2210408.05	GEORGIA NUTT RAMAY	8/11/2006	HOOD	2230	606	15665
TX	HOOD	TX2210408.05	GEORGIA NUTT RAMAY	8/11/2006
TX	HOOD	TX2210408.06	BRIAN A MACOMBER ET UX	3/31/2008	HOOD	2392	230	6647
TX	HOOD	TX2210408.06	BRIAN A MACOMBER ET UX	3/31/2008
TX	HOOD	TX2210408.09	AMY E SPEER	11/17/2014	HOOD			2015-0000667
TX	HOOD	TX2210411.01	PRENTICE BAKER ET UX	5/10/2006	HOOD	2211	490	11228
TX	HOOD	TX2210413.00	L B ROLLINS ET UX	4/26/2006	HOOD	2211	494	11229
TX	HOOD	TX2210414.00	KARAN SUE ROLLINS EXE ESTA	5/31/2006	HOOD	2211	497	11230
TX	HOOD	TX2210418.00	DANNY ROLLINS	6/13/2006	HOOD	2216	479	12441
TX	HOOD	TX2210420.01	WM G WHITECOTTON ET UX	6/21/2006	HOOD	2226	205	14686
TX	HOOD	TX2210420.02	BARBARA J MCDONALD	8/30/2007	HOOD	2335	294	16762
TX	HOOD	TX2210421.01	WILLIAM N HOFMANN ET UX	6/16/2006	HOOD	2230	608	15666
TX	HOOD	TX2210421.02	O P LEONARD JR ET AL	7/1/2009	HOOD	2493	50	9923
TX	HOOD	TX2210423.00	CHARLES GLENN VAUGHN ET UX	5/22/2006	HOOD	2223	708	14081
TX	HOOD	TX2210426.01	W C HAMMER ET UX	4/10/2006	HOOD	2218	487	12883
TX	HOOD	TX2210426.02	GARRY Z LUKER	4/10/2006	HOOD	2223	706	14080
TX	HOOD	TX2210426.03	WALTER CAVEN ET AL	5/1/2007	HOOD	2300	774	8621
TX	HOOD	TX2210426.03	WALTER CAVEN ET AL	5/1/2007
TX	HOOD	TX2210426.04	MABEL F REAVES	4/22/2008	HOOD	2405	721	9830
TX	HOOD	TX2210426.05	JASON M FOJTASEK ET UX	4/22/2008	HOOD	2405	724	9831
TX	HOOD	TX2210426.07	MICHELLE K GAMO	4/22/2008	HOOD	2405	739	9836
TX	HOOD	TX2210426.08	ALICE T HAMPTON	4/22/2008	HOOD	2405	696	9819
TX	HOOD	TX2210426.09	JEFFREY L BOKOR ET UX	4/22/2008	HOOD	2405	708	9824
TX	HOOD	TX2210426.11	JURGEN KEYS ET UX	4/22/2008	HOOD	2403	56	9196
TX	HOOD	TX2210426.12	TERESA FINN	4/22/2008	HOOD	2405	727	9832
TX	HOOD	TX2210426.13	ANICETO FLORES ET UX	4/22/2008	HOOD	2405	736	9835
TX	HOOD	TX2210426.14	HELEN FULFER	1/7/2008	HOOD	2377	650	3100
TX	HOOD	TX2210427.00	WYATT WIEDERKEHR ET UX	6/14/2006	HOOD	2211	486	11226
TX	HOOD	TX2210428.00	PERRY THOMAS DONAHOO ET UX	6/9/2006	HOOD	2223	703	14079
TX	HOOD	TX2210429.00	HOWARD GOODMAN	6/23/2006	HOOD	2218	480	12880
TX	HOOD	TX2210431.00	HAROLD L SANDEL JR	5/3/2006	HOOD	2211	488	11227
TX	HOOD	TX2210433.01	THE MABERY TRUST	6/16/2006	HOOD	2223	713	14083
TX	HOOD	TX2210433.02	FREELAN MABERY	8/14/2008	HOOD	2433	315	16306
TX	HOOD	TX2210434.00	RUTH LANDERS	7/26/2006	HOOD	2229	811	15510
TX	HOOD	TX2210436.00	FD-GRANBURY BEND LTD	7/12/2006	HOOD	2223	711	14082
TX	HOOD	TX2210439.00	SAMUEL C ARCHER	8/1/2006	HOOD	2229	807	15508
TX	HOOD	TX2210440.00	GRACE BIBLE CHURCH	7/12/2006	HOOD	2229	801	15505
TX	HOOD	TX2210445.00	HELEN E PONTIER ET VIR	8/21/2006	HOOD	2244	921	18992
TX	HOOD	TX2210448.00	GRANBURY CHURCH OF CHRIST	8/17/2006	HOOD	2230	614	15668
TX	HOOD	TX2210451.01	GARRY Z LUKER	7/5/2006	HOOD	2216	719	12481
TX	HOOD	TX2210451.02	CHARO INC	7/12/2006	HOOD	2217	120	12574
TX	HOOD	TX2210451.03	THOMAS RAY MARBUT	3/30/2009	HOOD	2474	142	5618
TX	HOOD	TX2210451.04	THOMAS MILLIGAN	5/28/2009	HOOD	2485	678	8155
TX	HOOD	TX2210451.05	JESSE L BRADLEY	4/22/2009	HOOD	2481	902	7310
TX	HOOD	TX2210451.06	MITCHELL O PRUITT	4/7/2009	HOOD	2481	922	7318
TX	HOOD	TX2210451.07	CONNIE MARY HABERN	5/21/2009	HOOD	2488	122	8725
TX	HOOD	TX2210451.08	BRYAN ROE	5/21/2009	HOOD	2488	125	8726
TX	HOOD	TX2210452.99	MARGARET RANEY	8/27/2006	HOOD	2237	795	17344
TX	HOOD	TX2210453.99	WILLIAM BYRON RANEY	8/30/2006	HOOD	2237	799	17346
TX	HOOD	TX2210454.99	TWILA JONES	8/27/2006	HOOD	2237	797	17345
TX	HOOD	TX2210456.00	MAXINE'S RESTAURANT	8/21/2006	HOOD	2236	783	17119
TX	HOOD	TX2210457.00	RANDY C JACKSON	8/27/2006	HOOD	2236	776	17116
TX	HOOD	TX2210458.00	JAMES L SMITH ET UX	8/21/2006	HOOD	2236	773	17115
TX	HOOD	TX2210459.01	CLAIBORNE ARCHER	8/1/2006	HOOD	2244	923	18993
TX	HOOD	TX2210459.01	CLAIBORNE ARCHER	8/1/2006
TX	HOOD	TX2210459.02	HENREIDA ARCHER JONES	8/3/2006	HOOD	2237	801	17347
TX	HOOD	TX2210459.02	HENREIDA ARCHER JONES	8/3/2006
TX	HOOD	TX2210460.00	ROBERT M LING ET UX	9/8/2006	HOOD	2241	377	18143
TX	HOOD	TX2210461.00	MARTIN L YARBOROUGH ET UX	9/14/2006	HOOD	2241	374	18142
TX	HOOD	TX2210463.00	HANFORD INC	8/2/2006	HOOD	2235	98	16715
TX	HOOD	TX2210465.00	WILLIAM G BRADLEY ET UX	9/7/2006	HOOD	2241	362	18138
TX	HOOD	TX2210466.00	DAVIDS PROPERTIES LP	9/21/2006	HOOD	2241	365	18139
TX	HOOD	TX2210468.00	KYLE D LONG ET UX	9/8/2006	HOOD	2241	368	18140
TX	HOOD	TX2210470.00	CALVIN LEON DAVIS ET UX	8/21/2006	HOOD	2247	200	19553
TX	HOOD	TX2210475.00	JIM D BENWARE ET UX	10/3/2006	HOOD	2242	833	18494
TX	HOOD	TX2210476.00	KEVIN W LONG ET UX	10/3/2006	HOOD	2248	181	19759
TX	HOOD	TX2210477.00	JACK M PEER SR ET UX	10/3/2006	HOOD	2248	172	19756
TX	HOOD	TX2210478.00	JAMES VICTOR PRINCE ET UX	9/28/2006	HOOD	2248	178	19758
TX	HOOD	TX2210479.00	WARREN M DAVENPORT ET UX	10/3/2006	HOOD	2248	169	19755
TX	HOOD	TX2210481.00	TRACIE K. SCOTT	9/14/2006	HOOD	2244	905	18986
TX	HOOD	TX2210482.00	ROBERT L. HIATT ET UX	9/14/2006	HOOD	2244	902	18985
TX	HOOD	TX2210483.00	DUANE M BLEEKER ET UX	9/28/2006	HOOD	2244	883	18978
TX	HOOD	TX2210484.00	J CALK OC ROLLINS TRST	9/26/2006	HOOD	2249	326	20013
TX	HOOD	TX2210485.00	BILLY JOE OLIVER JR. ET UX	9/12/2006	HOOD	2242	830	18493
TX	HOOD	TX2210486.00	STEPHEN W. LIVELY ET UX	9/11/2006	HOOD	2244	878	18976
TX	HOOD	TX2210487.00	BARRY N. SMITH ET UX	9/21/2006	HOOD	2248	161	19752
TX	HOOD	TX2210488.00	GAYLE MAX CALK ET UX	9/26/2006	HOOD	2244	885	18979
TX	HOOD	TX2210489.00	DECORDOVA ENERGY CO LP	10/16/2006	HOOD	2249	316	20009
TX	HOOD	TX2210490.00	RONALD P BERLIN	9/1/2006	HOOD	2232	521	16131
TX	HOOD	TX2210491.00	JASON ROGERS ET UX	10/5/2006	HOOD	2248	184	19760
TX	HOOD	TX2210492.00	REBECCA KOEHN	10/12/2006	HOOD	2248	175	19757
TX	HOOD	TX2210493.00	DALY R BALES JR ET UX	9/20/2006	HOOD	2248	163	19753
TX	HOOD	TX2210494.00	PEARLENE S PRICE	10/12/2006	HOOD	2248	167	19754
TX	HOOD	TX2210495.00	JEANNETTE CALK AIF ROLLINS	10/12/2006	HOOD	2244	881	18977
TX	HOOD	TX2210496.00	PHILIP W CRISWELL ET UX	9/19/2006	HOOD	2244	911	18988
TX	HOOD	TX2210497.00	MIRIAM KUGGA MONCRIEF TR	9/27/2006	HOOD	2244	914	18989
TX	HOOD	TX2210498.00	PARTEN FAMILY LIVING TR	10/9/2006	HOOD	2244	908	18987
TX	HOOD	TX2210500.00	ROY L KINNARD ET UX	10/9/2006	HOOD	2249	321	20011
TX	HOOD	TX2210501.00	KARIN DUNN	10/10/2006	HOOD	2248	187	19761
TX	HOOD	TX2210503.00	CAROL SUE MCRAE	9/30/2006	HOOD	2255	623	21414
TX	HOOD	TX2210504.00	CECIL M PYRON ET UX	10/5/2006	HOOD	2255	626	21415
TX	HOOD	TX2210505.00	CLIFFORD W WARNER	9/27/2006	HOOD	2248	150	19748
TX	HOOD	TX2210506.00	CHARLOTTE D BALLARD ET VIR	10/9/2006	HOOD	2248	156	19750
TX	HOOD	TX2210507.00	EARNEST R DERRICK ET AL	10/9/2006	HOOD	2248	147	19747
TX	HOOD	TX2210508.00	WILLIAM CRAIG DAVIS	10/15/2006	HOOD	2248	153	19749
TX	HOOD	TX2210510.00	MITCHELL BEND CEMETERY	10/11/2006	HOOD	2249	318	20010
TX	HOOD	TX2210511.00	LAKE GRANBURY CHRIST TEMP	10/10/2006	HOOD	2249	312	20007
TX	HOOD	TX2210516.01	RICHARD C BATES ET UX	9/1/2006	HOOD	2255	611	21409
TX	HOOD	TX2210516.02	TRI-RICH INC	9/1/2006	HOOD	2255	609	21408
TX	HOOD	TX2210516.03	GEORGE ARNOLD ET UX	9/1/2006	HOOD	2258	3	21976
TX	HOOD	TX2210516.04	DAN L GRIFFIN ET UX	9/1/2006	HOOD	2255	594	21402
TX	HOOD	TX2210522.00	RAY R YOUNG IN AIF M YOUNG	10/24/2006	HOOD	2249	291	19998
TX	HOOD	TX2210523.00	WILLIAM M MOORE ET UX	10/15/2006	HOOD	2249	297	20000
TX	HOOD	TX2210524.00	TOMMY RAY GREEN SR ET UX	9/30/2006	HOOD	2249	288	19997
TX	HOOD	TX2210525.00	DEBORAH J ALEXANDER	10/18/2006	HOOD	2249	282	19995
TX	HOOD	TX2210526.00	JOYCE CONKLIN	10/18/2006	HOOD	2249	285	19996
TX	HOOD	TX2210527.00	LEONARD D GROBER ET UX	10/15/2006	HOOD	2249	294	19999
TX	HOOD	TX2210529.00	BOLDLUCKK FAM LP D BALES	10/20/2006	HOOD	2255	586	21400
TX	HOOD	TX2210530.00	STEVE PRATER ET UX	10/20/2006	HOOD	2255	583	21399
TX	HOOD	TX2210531.00	JAMES K FULLER ET UX	10/9/2006	HOOD	2255	606	21407
TX	HOOD	TX2210532.00	GREGORY C WINTERS ET UX	10/27/2006	HOOD	2255	603	21406
TX	HOOD	TX2210533.00	RANDALL LEE MURPHY ET UX	10/9/2006	HOOD	2255	629	21416
TX	HOOD	TX2210534.00	MARY LOUISE HIDALGO	10/18/2006	HOOD	2255	617	21412
TX	HOOD	TX2210535.01	CHERYL LOUISE GILMORE	10/20/2006	HOOD	2255	620	21413
TX	HOOD	TX2210535.02	ROBERT GILMORE	12/21/2009	HOOD	2525	578	734
TX	HOOD	TX2210538.00	BARNEY W CAUBLE ET UX	10/5/2004	HOOD	2061	272	19792
TX	HOOD	TX2210543.00	BRYAN E MAULDIN ET UX	10/31/2006	HOOD	2255	598	21404
TX	HOOD	TX2210546.00	STEPHANIE SHELTON	10/28/2006	HOOD	2270	9	1378
TX	HOOD	TX2210549.00	EDWARD M BUTLER ET UX	11/13/2006	HOOD	2257	974	21963
TX	HOOD	TX2210550.00	DENNIS D NOTGRASS	11/8/2006	HOOD	2257	982	21966
TX	HOOD	TX2210551.00	EDWARD J DITTLINGER ET UX	10/27/2006	HOOD	2259	224	22271
TX	HOOD	TX2210552.00	DEAN JARMAN ET UX	11/6/2006	HOOD	2259	221	22270
TX	HOOD	TX2210553.00	CRAIG A SIMON ET UX	11/6/2006	HOOD	2259	200	22263
TX	HOOD	TX2210554.00	GARY D HORN ET UX	10/9/2006	HOOD	2259	208	22264
TX	HOOD	TX2210555.00	MICHAEL C CHESTNUT ET UX	11/6/2006	HOOD	2259	206	22265
TX	HOOD	TX2210556.00	LOLA JANICE DEWALD	10/25/2006	HOOD	2257	971	21962
TX	HOOD	TX2210559.00	EARL BAUCOM	9/30/2006	HOOD	2277	159	3142
TX	HOOD	TX2210560.00	ROBERT BISHOP OCONNER ETUX	10/28/2006	HOOD	2458	938	2173
TX	HOOD	TX2210561.00	ROBERT M WILLIAMS ET UX	11/27/2006	HOOD	2259	196	22261
TX	HOOD	TX2210565.00	JOSEPH R NEWMAN ET UX	11/21/2006	HOOD	2259	218	22269
TX	HOOD	TX2210566.00	ROBERT N GRAY	11/27/2006	HOOD	2270	92	1413
TX	HOOD	TX2210567.00	RONALD R CHEYNE TRST ET UX	11/21/2006	HOOD	2259	215	22268
TX	HOOD	TX2210568.00	DOLEN BARTOS ET UX	11/21/2006	HOOD	2259	209	22266
TX	HOOD	TX2210569.00	MARGARET FAYE ADAMS	11/21/2006	HOOD	2259	212	22267
TX	HOOD	TX2210570.01	R N GRAY & W F BENNIS	11/22/2006	HOOD	2298	666	8127
TX	HOOD	TX2210570.02	K GRAY AIF METCALF / CLAY	4/2/2007	HOOD	2298	640	8117
TX	HOOD	TX2210572.00	STEVEN MAX WARD ET UX	11/6/2006	HOOD	2270	71	1405
TX	HOOD	TX2210573.01	SATARI ENTERPRISES ET AL	11/14/2006	HOOD	ALL 2273	137 172 167 162 157 152 147 142	2159 2166 2165 2164 2163 2162 2161 2160
TX	HOOD	TX2210573.02	VERNA BARBER	12/13/2005	HOOD	2160	398	21200
TX	HOOD	TX2210573.02	VERNA BARBER	12/13/2005
TX	HOOD	TX2210573.03	TOMMY GARLAND ET UX	2/1/2007	HOOD	2281	939	4269
TX	HOOD	TX2210573.04	DANNY RAY GARRETT ET UX	2/7/2007	HOOD	2281	935	4267
TX	HOOD	TX2210573.05	MARGARET PRYOR	2/2/2007	HOOD	2281	937	4268
TX	HOOD	TX2210573.06	WILLIAM L COOK JR ET UX	2/19/2007	HOOD	2281	933	4266
TX	HOOD	TX2210573.07	GORDON W KENNEY ET UX	2/10/2007	HOOD	2281	931	4265
TX	HOOD	TX2210573.08	WILLIAM E GIBSON	2/7/2007	HOOD	2281	943	4270
TX	HOOD	TX2210573.09	LEE ANTHONY CHANDLER ET UX	2/7/2007	HOOD	2421	336	13517
TX	HOOD	TX2210575.00	WILLIAM F WALTERS	11/19/2006	HOOD	2270	65	1402
TX	HOOD	TX2210577.01	LEROY J HELF	11/20/2006	HOOD	2270	41	1391
TX	HOOD	TX2210577.02	JAMES MICHAEL PERRY	11/8/2006	HOOD	2270	38	1390
TX	HOOD	TX2210577.03	CHRYSTELLE C PERRY	11/8/2006	HOOD	2270	44	1392
TX	HOOD	TX2210580.00	SUNNYE L BURT REV TRST	11/28/2006	HOOD	2270	76	1407
TX	HOOD	TX2210581.00	MICHAEL E TALMAGE ET UX	10/27/2006	HOOD	2270	79	1408
TX	HOOD	TX2210583.00	FARRIS H WHEAT ET UX	1/6/2007	HOOD	2265	756	422
TX	HOOD	TX2210584.00	BYRON P SEARS ET UX	12/5/2006	HOOD	2270	14	1380
TX	HOOD	TX2210585.00	JAMES E HUNTER ET UX	12/5/2006	HOOD	2270	35	1389
TX	HOOD	TX2210586.00	KYU TAE PARK ET UX	11/10/2006	HOOD	2270	1	1375
TX	HOOD	TX2210587.00	RONALD J TOON ET UX	12/12/2006	HOOD	2270	24	1384
TX	HOOD	TX2210608.00	JERRY MOLDER ET UX	12/2/2006	HOOD	2270	85	1410
TX	HOOD	TX2210653.00	ROGER GEE	12/13/2006	HOOD	2270	67	1403
TX	HOOD	TX2210654.01	OTTO YATES ET UX	12/15/2006	HOOD	2270	61	1400
TX	HOOD	TX2210654.02	JEPTHA C TATUM III ET UX	1/5/2007	HOOD	2270	74	1406
TX	HOOD	TX2210655.00	REX D BRUTON ET UX	11/16/2006	HOOD	2270	87	1411
TX	HOOD	TX2210660.00	VIC ADAMS ET AL	12/5/2006	HOOD	2270	21	1383
TX	HOOD	TX2210667.00	MONTE C MERCER ET UX	12/3/2006	HOOD	2269	997	1373
TX	HOOD	TX2210668.00	WILLIAM G EMMETT ET UX	12/18/2006	HOOD	2270	3	1376
TX	HOOD	TX2210678.00	ROBIN HURST ET UX	12/3/2006	HOOD	2273	181	2169
TX	HOOD	TX2210682.00	BILLIE J BRIDGES	9/19/2006	HOOD	2241	371	18141
TX	HOOD	TX2210684.01	LAURA S CROSBY	12/15/2006	HOOD	2277	186	3152
TX	HOOD	TX2210684.02	CHARLES R SNAKARD	12/15/2006	HOOD	2277	181	3151
TX	HOOD	TX2210684.03	SHELLEY KAY SASS TRUST	3/12/2007	HOOD	2289	221	5921
TX	HOOD	TX2210687.00	JOE M MOLDER ET UX	1/11/2007	HOOD	2281	914	4257
TX	HOOD	TX2210692.00	MERRITHEW & MERRITHEW	1/13/2007	HOOD	2281	925	4262
TX	HOOD	TX2210693.00	GANTT FAMILY LIVING TRUST	1/13/2007	HOOD	2281	923	4261
TX	HOOD	TX2210694.01	CRISP FAMILY LP	12/17/2006	HOOD	2276	211	92900
TX	HOOD	TX2210694.02	YVONNE READ ET VIR	10/23/2003	HOOD	1977	469	559
TX	HOOD	TX2210694.02	YVONNE READ ET VIR	10/23/2003
TX	HOOD	TX2210698.00	RANDY W SOLOMON ET UX	2/23/2007	HOOD	2281	869	4240
TX	HOOD	TX2210700.00	TAMATHA HURST	2/15/2007	HOOD	2276	920	3078
TX	HOOD	TX2210710.01	DAN V DENT ET UX	1/21/2007	HOOD	2284	501	4830
TX	HOOD	TX2210710.02	A LEE HARRIS ET UX	1/21/2007	HOOD	2284	513	4835
TX	HOOD	TX2210714.00	FRED FAYYAZI	1/16/2007	HOOD	2277	375	3217
TX	HOOD	TX2210715.00	MICHAEL V KELLY ET UX	2/26/2007	HOOD	2281	871	4241
TX	HOOD	TX2210723.00	JAMES G WALSH TRUSTEE	3/7/2007	HOOD	2283	264	4618
TX	HOOD	TX2210724.00	EDNA LOUISE MCQUEEN	2/6/2007	HOOD	2284	505	4832
TX	HOOD	TX2210735.00	HENRY MILTON MOLDER ET UX	3/1/2007	HOOD	2289	196	5912
TX	HOOD	TX2210741.01	MARGARET DENISE DUNBAR	3/8/2007	HOOD	2289	237	5929
TX	HOOD	TX2210741.02	DEE ANN DENT ET VIR	2/23/2007	HOOD	2298	670	8129
TX	HOOD	TX2210741.03	LARRY D HUFF	3/16/2007	HOOD	2289	239	5930
TX	HOOD	TX2210741.04	WILLIAM E HUFF	3/8/2007	HOOD	2289	241	5931
TX	HOOD	TX2210744.00	RED ROCK ENTERPRISES LLC	2/23/2007	HOOD	2293	576	7000
TX	HOOD	TX2210751.00	FRED F FAYYAZI	3/1/2007	HOOD	2293	571	6998
TX	HOOD	TX2210752.00	DANNY W WILLS ET UX	3/24/2007	HOOD	2293	587	7004
TX	HOOD	TX2210756.00	VAN GRIFFITH ET UX	3/26/2007	HOOD	2293	556	6991
TX	HOOD	TX2210759.00	ACTON CENTRE LLC	3/26/2007	HOOD	2293	574	6999
TX	HOOD	TX2210760.00	RONALD J DAVIS ET UX	3/25/2007	HOOD	2293	584	7003
TX	HOOD	TX2210761.00	TAMATHA HURST	4/5/2007	HOOD	2293	567	6996
TX	HOOD	TX2210762.01	JAMES G WALSH TRUSTEE	3/7/2007	HOOD	2293	558	6992
TX	HOOD	TX2210762.02	ROBERT ADAIR ET UX	12/22/2006	HOOD	2270	17	1381
TX	HOOD	TX2210763.00	DAVID A SCHOENER ET UX	3/26/2007	HOOD	2298	679	8133
TX	HOOD	TX2210764.00	EDWARD J PULTORAK ET UX	3/27/2007	HOOD	2298	682	8134
TX	HOOD	TX2210765.00	CHARLES R WHITEHEAD ET UX	3/27/2007	HOOD	2298	688	8136
TX	HOOD	TX2210766.00	LARRY DALE BARNES ET UX	3/25/2007	HOOD	2293	590	7005
TX	HOOD	TX2210768.00	DARYL PITTS ET UX	3/26/2007	HOOD	2298	685	8135
TX	HOOD	TX2210771.00	GEORGE H MOORE ET UX	4/18/2007	HOOD	2298	668	8128
TX	HOOD	TX2210772.00	KATHLEEN NEWLAND	3/27/2007	HOOD	2298	654	8122
TX	HOOD	TX2210775.00	FAYNE MULLEN ET UX	11/6/2006	HOOD	2298	696	8139
TX	HOOD	TX2210776.00	HOOD COUNTY HUMANE SOCIETY	2/12/2007	HOOD	2298	643	8118
TX	HOOD	TX2210783.00	FALL CREEK COMMUNITY CENTE	4/16/2007	HOOD	2297	851	7959
TX	HOOD	TX2210784.00	FALL CREEK CEMETERY	4/16/2007	HOOD	2297	849	7958
TX	HOOD	TX2210785.00	WILLIAM D PIKE ET UX	4/16/2007	HOOD	2300	803	8626
TX	HOOD	TX2210787.01	GLENDA PARK ET VIR	1/15/2009	HOOD	2467	23	3994
TX	HOOD	TX2210787.02	KENNETH Z MILLER ET UX	1/12/2009	HOOD	2467	27	3995
TX	HOOD	TX2210787.03	TWILA M WAKEFIELD SMITH	1/26/2009	HOOD	2467	19	3993
TX	HOOD	TX2210787.04	LEONARD O HEATHINGTON ET U	4/9/2007	HOOD	2324	649	14320
TX	HOOD	TX2210787.05	SHERRY MADDOX	1/15/2009	HOOD	2467	31	3996
TX	HOOD	TX2210787.06	HARLEY M ROLLINS EST	3/24/2009	HOOD	2480	297	6926
TX	HOOD	TX2210898.00	EQUIBRAND PRODUCTS GRP LP	4/16/2007	HOOD	2304	606	9551
TX	HOOD	TX2210909.00	DANIEL R NAYLOR ET UX	3/25/2007	HOOD	2308	942	10642
TX	HOOD	TX2210912.00	SILVER BULLET OIL & GAS	5/28/2007	HOOD	2309 AND 2311	345 AND 560	10761 AND 11283
TX	HOOD	TX2210937.00	CHRISTOPHER E MONTES ET UX	4/25/2007	HOOD	2318	281	12834
TX	HOOD	TX2210939.00	EARL ECKELS	5/15/2007	HOOD	2308	741	10584
TX	HOOD	TX2210940.00	GROUP W, LTD A TX LMTED PA	5/30/2007	HOOD	2318	235	12815
TX	HOOD	TX2210955.00	DICK BRUTON	4/18/2007	HOOD	2324	656	14323
TX	HOOD	TX2210956.00	EDWIN LEON HANKINS ET UX	6/5/2007	HOOD	2333	507	16310
TX	HOOD	TX2210957.02	KELLY SEALEY HOPPER	6/9/2007	HOOD	2357	878	21996
TX	HOOD	TX2210957.03	CAROL RHOADES SEALEY	6/9/2007	HOOD	2357	876	21995
TX	HOOD	TX2210957.04	J WILLIAM CARTER ET UX	12/12/2007	HOOD	2373	83	2184
TX	HOOD	TX2210957.05	MIRIAM CARTER BRUCE	12/12/2007	HOOD	2373	100	2191
TX	HOOD	TX2210957.06	GENE A CARTER ET UX	12/12/2007	HOOD	2373	153	2210
TX	HOOD	TX2210957.07	GLENDA CARTER YORK ET VIR	12/12/2007	HOOD	2373	66	2176
TX	HOOD	TX2210957.08	BETTY CARTER	12/12/2007	HOOD	2373	98	2190
TX	HOOD	TX2210957.09	JOHN L CARTER ET UX	12/12/2007	HOOD	2373	54	2170
TX	HOOD	TX2210957.10	MARY ANN CARTER	12/12/2007	HOOD	2382	32	4131
TX	HOOD	TX2210957.11	JOY CARTER JOHNSTONE	12/12/2007	HOOD	2373	56	2171
TX	HOOD	TX2210957.12	FAYE NELL HERM	12/12/2007	HOOD	2373	64	2175
TX	HOOD	TX2210957.13	STEVEN CARTER ET UX	12/12/2007	HOOD	2373	62	2174
TX	HOOD	TX2210957.14	MARY ANNE BENTON ET VIR	12/12/2007	HOOD	2382	71	4147
TX	HOOD	TX2210957.15	SUSAN CARTER SPORTSMAN	1/8/2008	HOOD	2382	10	4122
TX	HOOD	TX2210957.16	ROBERT CARTER ET UX	12/12/2007	HOOD	2382	39	4134
TX	HOOD	TX2210957.17	KAREN CARTER WADE ET VIR	12/12/2007	HOOD	2382	67	4145
TX	HOOD	TX2210957.18	MEGAN LYNN LONGTON	6/10/2010	HOOD			2010-0007760
TX	HOOD	TX2210957.19	MANDY HOLDERNESS	6/10/2010	HOOD			2010-0007757
TX	HOOD	TX2210963.00	PERRY WAYNE NATIONS ET UX	6/25/2007	HOOD	2324	654	14322
TX	HOOD	TX2210972.01	JERE RANDOL LANCASTER ETUX	6/25/2007	HOOD	2321	194	13525
TX	HOOD	TX2210972.02	VERDETTA MAURINE LANCASTER	6/25/2007	HOOD	2321	196	13526
TX	HOOD	TX2210980.99	BEN KLIMIST J KLIMIST	8/1/2007	HOOD	2328	263	15106
TX	HOOD	TX2210981.99	MILDRED KLIMIST	8/1/2007	HOOD	2328	266	15107
TX	HOOD	TX2210990.13	MARLENE CHAMPION ET VIR	9/22/2010	HOOD			2010-0012219
TX	HOOD	TX2210990.14	MARLENE CHAMPION ET VIR	9/22/2010	HOOD			2010-0012220
TX	HOOD	TX2210990.15	MAXINE TUCKER ET VIR	9/27/2010	HOOD			2010-0012888
TX	HOOD	TX2210990.16	MAXINE TUCKER ET VIR	9/27/2010	HOOD			2010-0012889
TX	HOOD	TX2210990.17	GWENDEAN DYRUD ET VIR	10/21/2010	HOOD			2010-0012891
TX	HOOD	TX2210990.18	GWENDEAN DYRUD ET VIR	10/21/2010	HOOD			2010-0012890
TX	HOOD	TX2210990.19	MYRLENE DEERING HOLDER	11/15/2010	HOOD			2010-0013445
TX	HOOD	TX2210990.20	GERALD MUSICK ET UX	11/17/2010	HOOD			2010-0013444
TX	HOOD	TX2210990.23	MYRNA WELLS	1/4/2011	HOOD			2011-0001094
TX	HOOD	TX2210990.26	DAVID ADAMS	12/11/2013	HOOD			2014-0000720
TX	HOOD	TX2210990.27	DAVID ADAMS	12/11/2013	HOOD			2014-0000719
TX	HOOD	TX2210990.28	DELPHINE I DEERING COUNTS	12/17/2013	HOOD			2014-0000718
TX	HOOD	TX2210990.29	H D STORY II	11/18/2014	HOOD			2015-0003651
TX	HOOD	TX2210991.01	JAMES D WALLS ET UX	7/20/2007	HOOD	2333	553	16329
TX	HOOD	TX2210991.03	SHERILYN GREGORY	11/4/2010	HOOD			2010-0013110
TX	HOOD	TX2210991.04	GEORGE LEE HAWPE	11/4/2010	HOOD			2010-0013111
TX	HOOD	TX2210991.05	RICHARD LEROY BYBEE	11/4/2010	HOOD			2010-0013113
TX	HOOD	TX2210991.06	TOMMIE THORNTON ET UX	7/30/2007	HOOD	2333	547	16327
TX	HOOD	TX2211002.00	GAYLAND EUGENE CARTER	8/10/2007	HOOD	2336	24	16932
TX	HOOD	TX2211003.00	RONNEY J EVERETTE ET UX	8/10/2007	HOOD	2336	69	16954
TX	HOOD	TX2211005.00	LORETTA F EVERETTE	8/10/2007	HOOD	2336	30	16935
TX	HOOD	TX2211006.00	WINNIFRED CARTER ET AL	8/10/2007	HOOD	2336	22	16931
TX	HOOD	TX2211009.00	DONALD G HOLLAND ET UX	8/10/2007	HOOD	2336	61	16950
TX	HOOD	TX2211010.00	DAVID CLEVELAND ET UX	8/11/2007	HOOD	2333	521	16317
TX	HOOD	TX2211011.00	ALTON LEE LOCKETT ET UX	8/10/2007	HOOD	2336	28	16934
TX	HOOD	TX2211012.00	LYNDELL RAY LOCKETT ET UX	8/10/2007	HOOD	2336	26	16933
TX	HOOD	TX2211013.00	DWAIN DANIELS ET UX	8/10/2007	HOOD	2340	32	17940
TX	HOOD	TX2211014.00	WILLIAM M DANIELS ET UX	8/10/2007	HOOD	2342	836	18512
TX	HOOD	TX2211015.00	KEITH LANDON KUNKEL ET UX	8/10/2007	HOOD	2336	57	16948
TX	HOOD	TX2211016.01	MURLE BLASINGAME ET UX	8/10/2007	HOOD	2336	55	16947
TX	HOOD	TX2211016.02	JOHN GRESHAM ET UX	12/23/2009	HOOD	2523	303	140
TX	HOOD	TX2211017.00	RICHARD PAUL NEWMAN ET UX	7/9/2007	HOOD	2333	532	16322
TX	HOOD	TX2211023.00	NATHAN MILTON BLASINGAME	8/10/2007	HOOD	2336	53	16946
TX	HOOD	TX2211024.00	MICHAEL PATE ET UX	8/15/2007	HOOD	2336	47	16943
TX	HOOD	TX2211026.00	DENNY KRAMER ET UX	8/10/2007	HOOD	2336	49	16944
TX	HOOD	TX2211027.00	JEROME PAUL KUNKEL ET UX	8/20/2007	HOOD	2336	71	16955
TX	HOOD	TX2211030.00	GILBERT C SCRIVNER ET UX	8/28/2007	HOOD	2336	517	17081
TX	HOOD	TX2211032.01	JAMES W HARDIN ET UX	8/19/2007	HOOD	2336	1000	17199
TX	HOOD	TX2211032.02	CECIL N HARDIN ET UX	8/19/2007	HOOD	2337	1	17200
TX	HOOD	TX2211034.00	JAMES M BELLEAU ET UX	8/8/2007	HOOD	2340	30	17938
TX	HOOD	TX2211035.00	JIM CREEK	8/20/2007	HOOD	2336	38	16939
TX	HOOD	TX2211037.00	JERRY SLEMMONS ET UX	8/19/2007	HOOD	2337	960	17434
TX	HOOD	TX2211038.01	JANET B CONNER HOLMES	9/6/2007	HOOD	2336	45	16942
TX	HOOD	TX2211038.02	WESLEY E HOLMES	11/25/2009	HOOD	2518	661	16189
TX	HOOD	TX2211040.01	JAMES D EVERETTE ET UX	9/3/2007	HOOD	2342	787	18492
TX	HOOD	TX2211040.02	JAMES C EVERETTE ET UX	9/3/2007	HOOD	2342	785	18491
TX	HOOD	TX2211041.01	ALTON L LOCKETT ET UX	8/10/2007	HOOD	2340	36	17942
TX	HOOD	TX2211041.02	LYNDELL RAY LOCKETT ET UX	8/10/2007	HOOD	2340	34	17941
TX	HOOD	TX2211046.00	MODENA OSBORNE	8/29/2007	HOOD	2340	38	17943
TX	HOOD	TX2211053.01	SANDRA LEE GODWIN	8/10/2007	HOOD	2342	801	18498
TX	HOOD	TX2211053.02	WESLEY LESTER GODWIN	8/10/2007	HOOD	2342	805	18500
TX	HOOD	TX2211053.03	WENDY GODWIN HOLLEY	8/10/2007	HOOD	2342	807	18501
TX	HOOD	TX2211053.04	BRADLEY L STEPHENS ET UX	8/10/2007	HOOD	2342	803	18499
TX	HOOD	TX2211053.05	SANDRA KAY AHRENS	12/5/2009	HOOD	2520	3	16546
TX	HOOD	TX2211053.07	ALICE BIGGS	12/5/2009	HOOD	2520	805	16769
TX	HOOD	TX2211053.09	DENNIS KINSON	12/5/2009	HOOD	2520	803	16768
TX	HOOD	TX2211053.10	ROGER DON BIGGS ET UX	12/5/2009	HOOD	2524	195	375
TX	HOOD	TX2211053.11	ESTELLE BIGGS	12/5/2009	HOOD	2524	192	374
TX	HOOD	TX2211053.12	MARY GAYLE CATES	12/5/2009	HOOD	2524	198	376
TX	HOOD	TX2211053.13	LINDA TURNER	12/5/2009	HOOD	2524	213	381
TX	HOOD	TX2211053.15	PATRICIA MARSH	12/5/2009	HOOD	2528	413	1410
TX	HOOD	TX2211053.16	CHARLES KINSON	12/5/2009	HOOD	2525	563	729
TX	HOOD	TX2211053.17	ALBERT G BIGGS	12/5/2009	HOOD	2528	416	1411
TX	HOOD	TX2211053.19	CHARLOTTE LEE	12/5/2009	HOOD	2535	446	3114
TX	HOOD	TX2211053.21	MANDY CHALET BIGGS	10/20/2010	HOOD			2010-0013793
TX	HOOD	TX2211057.00	HARVEY D PATTERSON SR ET U	7/20/2007	HOOD	2340	49	17949
TX	HOOD	TX2211058.00	PAM A DAVIS	9/6/2007	HOOD	2340	65	17956
TX	HOOD	TX2211059.00	JC BALDREE ET UX	9/4/2007	HOOD	2340	48	17948
TX	HOOD	TX2211061.00	RONNEY J EVERETTE ET UX	9/19/2007	HOOD	2340	41	17945
TX	HOOD	TX2211066.00	BRAZOS ELECTRIC POWER COOP	8/19/2007	HOOD	2339 AND 2339	910 AND 915	17904 AND 17905
TX	HOOD	TX2211072.00	CHRISTIAN A MILLER ET UX	8/29/2007	HOOD	2342	819	18506
TX	HOOD	TX2211074.00	MARY HELEN SMITH	7/20/2007	HOOD	2349	678	20092
TX	HOOD	TX2211075.00	JAMES MICHAEL DAVIS ET UX	9/13/2007	HOOD	2342	815	18505
TX	HOOD	TX2211082.00	MIKE BLEVINS ET UX	9/17/2007	HOOD	2345	98	19014
TX	HOOD	TX2211083.00	WANDA SWAIM	8/21/2007	HOOD	2349	669	20088
TX	HOOD	TX2211084.00	JESS REED ET UX	10/10/2007	HOOD	2345	94	19012
TX	HOOD	TX2211084.00	JESS REED ET UX	10/10/2007
TX	HOOD	TX2211085.00	MARGARET E ENDICOTT	9/27/2007	HOOD	2345	96	19013
TX	HOOD	TX2211086.00	WILLIAM L LOWE ET UX	10/10/2007	HOOD	2349	676	20091
TX	HOOD	TX2211095.01	TRACY L LOOS	11/8/2007	HOOD	2369	283	1329
TX	HOOD	TX2211095.02	MICHAEL W MORRISON	11/8/2007	HOOD	2357	898	22006
TX	HOOD	TX2211095.03	TONI D HEAPS	11/8/2007	HOOD	2360	604	22648
TX	HOOD	TX2211095.04	CHARLES E MORRISON	11/8/2007	HOOD	2373	102	2192
TX	HOOD	TX2211095.05	W A MORRISON JR	11/8/2007	HOOD	2357	896	22005
TX	HOOD	TX2211112.00	STONE HILL CORP	11/5/2007	HOOD	2354	766	21273
TX	HOOD	TX2211114.00	PHILIP W COPELAND ET AL	11/7/2007	HOOD	2354	768	21274
TX	HOOD	TX2211118.99	ARLIE NEWTON	10/30/2007	HOOD	2358	434	22144
TX	HOOD	TX2211123.00	WILLIE C WALKER TAPP ESTATE	11/2/2007	HOOD	2360	606	22649
TX	HOOD	TX2211124.00	MONARCH UTILITIES ILP	10/1/2007	HOOD	2357	886	22000
TX	HOOD	TX2211126.00	T JACKSON AIF FOR RUSSELL	11/10/2007	HOOD	2355	581	21490
TX	HOOD	TX2211127.01	CAROL RHOADES SEALEY	11/15/2007	HOOD	2357	882	21998
TX	HOOD	TX2211127.02	PHYLLIS LYNN DAVIS	11/15/2007	HOOD	2357	880	21997
TX	HOOD	TX2211127.02	PHYLLIS LYNN DAVIS	11/15/2007
TX	HOOD	TX2211127.03	KELLY SEALEY HOPPER	11/15/2007	HOOD	2357	884	21999
TX	HOOD	TX2211128.01	ALTON L LOCKETT ET UX	10/3/2007	HOOD	2357	894	22004
TX	HOOD	TX2211128.02	LYNDELL RAY LOCKETT ET UX	10/3/2007	HOOD	2357	892	22003
TX	HOOD	TX2211130.00	1ST NATIONAL BANK GRANBURY	11/20/2007	HOOD	2360	602	22647
TX	HOOD	TX2211134.00	WILLIE L DICKSON	9/13/2007	HOOD	2340	52	17950
TX	HOOD	TX2211135.00	BETTY DARLINE DAVIS	12/6/2007	HOOD	2362	668	23128
TX	HOOD	TX2211138.00	RAY BANFIELD JR	12/5/2007	HOOD	2364	548	232
TX	HOOD	TX2211139.00	ACTON UNITED METHODIST CH	11/28/2007	HOOD	2364	551	233
TX	HOOD	TX2211141.00	CLYDE MULLINS ET UX	9/24/2007	HOOD	2364	553	234
TX	HOOD	TX2211146.00	JACQUELYN L BLACKBURN	12/12/2007	HOOD	2369	262	1321
TX	HOOD	TX2211147.00	BARBARA BANFIELD	12/5/2007	HOOD	2369	293	1333
TX	HOOD	TX2211148.00	LEONARD HEATHINGTON ET UX	11/27/2007	HOOD	2369	266	1323
TX	HOOD	TX2211150.00	DAVID NEIL HARDIN ET UX	12/12/2007	HOOD	2369	272	1325
TX	HOOD	TX2211151.01	TOM DURANT ET UX	12/8/2007	HOOD	2382	46	4137
TX	HOOD	TX2211151.01	TOM DURANT ET UX	12/8/2007
TX	HOOD	TX2211151.02	ODYENE ELLIS LOONEY	12/8/2007	HOOD	2382	36	4133
TX	HOOD	TX2211151.02	ODYENE ELLIS LOONEY	12/8/2007
TX	HOOD	TX2211151.03	JERE R LANCASTER ET UX	12/8/2007	HOOD	2373	118	2198
TX	HOOD	TX2211151.03	JERE R LANCASTER ET UX	12/8/2007
TX	HOOD	TX2211151.03	JERE R LANCASTER ET UX	12/8/2007
TX	HOOD	TX2211151.04	RONALD B SEIDEL ET UX	12/8/2007	HOOD	2382	49	4138
TX	HOOD	TX2211151.04	RONALD B SEIDEL ET UX	12/8/2007
TX	HOOD	TX2211151.05	RALPH H WALTON JR ET UX	12/8/2007	HOOD	2373	112	2196
TX	HOOD	TX2211151.05	RALPH H WALTON JR ET UX	12/8/2007
TX	HOOD	TX2211151.06	WILLIAM L LOWE ET UX	12/8/2007	HOOD	2373	115	2197
TX	HOOD	TX2211151.06	WILLIAM L LOWE ET UX	12/8/2007
TX	HOOD	TX2211151.07	CLIFFORD GRANBERRY SR ETUX	12/8/2007	HOOD	2382	77	4150
TX	HOOD	TX2211151.07	CLIFFORD GRANBERRY SR ETUX	12/8/2007
TX	HOOD	TX2211153.00	MARSHALL RAINES	12/10/2007	HOOD	2369	290	1332
TX	HOOD	TX2211154.00	LYNDELL RAY LOCKETT ET UX	1/7/2008	HOOD	2369	300	1336
TX	HOOD	TX2211155.00	JOHN J HOWITZ ET UX	12/6/2007	HOOD	2373	72	2179
TX	HOOD	TX2211156.00	JEANEEN R DUFFEY ET VIR	12/5/2007	HOOD	2373	75	2180
TX	HOOD	TX2211158.00	WAYNE L COYER ET UX	11/27/2007	HOOD	2369	280	1328
TX	HOOD	TX2211160.00	EARL L MCDONALD ET UX	12/12/2007	HOOD	2369	275	1326
TX	HOOD	TX2211161.00	GLENN J LEBLANC ET UX	9/6/2007	HOOD	2342	796	18496
TX	HOOD	TX2211162.00	JAMES R GALLMAN	1/6/2007	HOOD	2291	895	6590
TX	HOOD	TX2211163.00	GERALD D AUSTIN	1/5/2007	HOOD	2334	854	16645
TX	HOOD	TX2211164.00	ACTON FIRST BAPTIST CHURCH	11/26/2007	HOOD	2369	306	1339
TX	HOOD	TX2211170.01	WILLIAM J HALBERT ET UX	1/4/2008	HOOD	2381	990	4115
TX	HOOD	TX2211170.02	LONNIE KYLE HALBERT ET UX	1/4/2008	HOOD	2381	994	4116
TX	HOOD	TX2211170.03	HATTIE LOU H ADAMS ET UX	1/4/2008	HOOD	2373	144	2207
TX	HOOD	TX2211170.04	ROBT L FOREE JR ET AL	1/24/2008	HOOD	2391	977	6587
TX	HOOD	TX2211171.00	MARION H CORNELIUS ET UX	1/14/2008	HOOD	2373	93	2188
TX	HOOD	TX2211172.00	JAMES O DICKENS ET UX	12/12/2007	HOOD	2369	315	1342
TX	HOOD	TX2211173.00	DANIEL BURENHEIDE ET UX	12/12/2007	HOOD	2369	312	1341
TX	HOOD	TX2211174.00	W T WILLINGHAM ET AL	11/29/2007	HOOD	2369	302	1337
TX	HOOD	TX2211176.01	CLARENCE W VAUGHN JR ET UX	1/2/2008	HOOD	2373	172	2219
TX	HOOD	TX2211177.01	VENABLE ROYALTY LTD	1/8/2008	HOOD	2373	58	2172
TX	HOOD	TX2211177.02	VENRO LTD	1/8/2008	HOOD	2373	60	2173
TX	HOOD	TX2211177.03	WAYLON DANIELS ET AL	8/10/2007	HOOD	2354	961	21324
TX	HOOD	TX2211177.04	WAYLON G DANIELS ET UX	8/10/2007	HOOD	2340	39	17944
TX	HOOD	TX2211178.01	BARBARA J MCDONALD	1/9/2008	HOOD	2366	928	795
TX	HOOD	TX2211178.02	WM G WHITECOTTON ET UX	9/21/2007	HOOD	2338	439	17561
TX	HOOD	TX2211180.00	CECELIA DIANE WALLACE	12/10/2007	HOOD	2374	191	2424
TX	HOOD	TX2211182.00	JAMES E DYSON ET UX	1/15/2008	HOOD	2373	68	2177
TX	HOOD	TX2211183.00	CARROL W SCOTT ET UX	1/15/2008	HOOD	2382	14	4124
TX	HOOD AND SOMERVELL	TX2211184.01	JANICE SUSAN HUGHES ET VIR	12/4/2007	HOOD	2419	603	13096
TX	HOOD AND SOMERVELL	TX2211184.01	JANICE SUSAN HUGHES ET VIR	12/4/2007	SOMERVELL			20080284
TX	HOOD	TX2211185.00	CHARLES JASON BRITT ET UX	9/14/2007	HOOD	2373	108	2195
TX	HOOD	TX2211186.01	RALPH H WALTON ET UX	1/18/2008	HOOD	2373	164	2215
TX	HOOD	TX2211186.02	ODYENE ELLIS LOONEY	1/18/2008	HOOD	2373	166	2216
TX	HOOD	TX2211186.03	JERE RANDOL LANCASTER ETUX	1/18/2008	HOOD	2373	168	2217
TX	HOOD	TX2211186.04	WILLIAM L LOWE ET UX	1/18/2008	HOOD	2373	170	2218
TX	HOOD	TX2211186.05	CLIFFORD GRANBERRY SR ETUX	1/18/2008	HOOD	2373	162	2214
TX	HOOD	TX2211186.06	TOM DURANT ET UX	1/18/2008	HOOD	2373	160	2213
TX	HOOD	TX2211186.07	RONALD B SEIDEL ET UX	1/18/2008	HOOD	2373	158	2212
TX	HOOD	TX2211188.00	STANLEY E KEETON ET UX	1/17/2008	HOOD	2373	106	2194
TX	HOOD	TX2211189.00	CRAIG ROWLAND ET UX	12/6/2007	HOOD	2373	129	2202
TX	HOOD	TX2211190.00	ROBERT V CAREY ET UX	12/6/2007	HOOD	2373	123	2200
TX	HOOD	TX2211191.00	KENNETH R ROBINSON ET UX	12/10/2007	HOOD	2373	155	2211
TX	HOOD	TX2211192.00	RODGER A RAWLEIGH ET UX	12/10/2007	HOOD	2373	150	2209
TX	HOOD	TX2211193.00	ROBERT S RIGGS ET UX	1/14/2008	HOOD	2382	34	4132
TX	HOOD	TX2211195.01	STEVEN C ELY ET UX	1/22/2008	HOOD	2382	23	4128
TX	HOOD	TX2211197.00	KATHRYN J JIVIDEN	12/12/2007	HOOD	2382	29	4130
TX	HOOD	TX2211201.00	TERRY E COX ASSOC LLC	1/30/2008	HOOD	2373	121	2199
TX	HOOD	TX2211202.00	KAREN K ISLIKER	12/10/2007	HOOD	2373	132	2203
TX	HOOD	TX2211203.00	SHAWN ALLEN ET UX	12/6/2007	HOOD	2373	135	2204
TX	HOOD	TX2211204.00	HERBERT T EARNEST TRST	12/9/2007	HOOD	2373	141	2206
TX	HOOD	TX2211205.00	JOHN HARVEY	12/10/2007	HOOD	2373	138	2205
TX	HOOD	TX2211206.00	HERMAN L MITCHELL	12/9/2007	HOOD	2373	147	2208
TX	HOOD	TX2211207.00	JAMES E STEWART ESTATE	1/11/2008	HOOD	2375	53	2540
TX	HOOD	TX2211209.00	LANNY T G LANCASTER	4/30/2003	HOOD	1927	885	10635
TX	HOOD	TX2211211.00	JEFFREY R KUTAS ET UX	1/24/2008	HOOD	2382	44	4136
TX	HOOD	TX2211216.00	KENNETH HOLDER	12/9/2007	HOOD	2382	64	4144
TX	HOOD	TX2211219.00	DENISE LIZUN	2/22/2008	HOOD	2389	345	5859
TX	HOOD	TX2211225.00	DAVID A WATSON ET UX	12/6/2007	HOOD	2389	351	5861
TX	HOOD	TX2211227.01	DILLARD A HOLLAND ET UX	2/26/2008	HOOD	2392	221	6644
TX	HOOD	TX2211228.00	JOE WOODY ET UX	3/4/2008	HOOD	2392	213	6639
TX	HOOD	TX2211230.00	D&D VICKERS TRST 7/10/90	1/4/2008	HOOD	2389	359	5864
TX	HOOD	TX2211231.00	DAN E HUNTER ET UX	3/5/2008	HOOD	2389	366	5867
TX	HOOD	TX2211233.00	WANDA FLANARY	3/4/2008	HOOD	2392	214	6640
TX	HOOD AND JOHNSON	TX2211235.00	ST TX M 108832 / M MOONEY ET UX	2/26/2008	HOOD	2384	675	4708
TX	HOOD AND JOHNSON	TX2211235.00	ST TX M 108832 / M MOONEY ET UX	2/26/2008	JOHNSON	4319	694	10976
TX	HOOD	TX2211238.00	VIDAMAR ENTERPRISES INC	3/3/2008	HOOD	2389	381	5873
TX	HOOD	TX2211239.00	BARTO L WADE	3/13/2008	HOOD	2389	373	5870
TX	HOOD	TX2211244.01	LYNDELL RAY LOCKETT ET UX	2/16/2008	HOOD	2392	206	6636
TX	HOOD	TX2211244.02	ALTON L LOCKETT ET UX	2/16/2008	HOOD	2392 AND 2517	204 AND 351	6635 AND 15854
TX	HOOD	TX2211245.00	HOOD COUNTY HOME SOURCE IN	3/17/2008	HOOD	2392	217	6642
TX	HOOD	TX2211246.00	RICHARD G BOEN ET UX	3/17/2008	HOOD	2392	215	6641
TX	HOOD	TX2211248.00	DONALD L MACFARLANE / VLB	12/6/2001	HOOD	1815	42	3908
TX	HOOD	TX2211249.00	EDWARD A BABBE ET UX	3/11/2008	HOOD	2392	238	6650
TX	HOOD	TX2211252.00	RICHARD W WILKERSON JR ET	8/24/2006	HOOD	2259	938	22444
TX	HOOD	TX2211253.01	KERRY SMITH ET UX	11/27/2007	HOOD	2392	196	6632
TX	HOOD	TX2211254.01	HOPKINS 2006 IRREV TR #1	3/20/2008	HOOD	2392	180	6626
TX	HOOD	TX2211254.02	HOPKINS 2006 IRREV TR #2	3/20/2008	HOOD	2392	178	6625
TX	HOOD	TX2211254.03	DECEDENTS TRUST B	3/20/2008	HOOD	2392	182	6627
TX	HOOD	TX2211255.00	THURMAN WAYNE PIDGEON ET U	4/2/2008	HOOD	2396	21	7513
TX	HOOD	TX2211256.00	AMY LAINE NEAL TRST	12/4/2007	HOOD	2392	185	6628
TX	HOOD	TX2211257.00	JOHN A ESPARZA ET UX	3/5/2008	HOOD	2392	188	6629
TX	HOOD	TX2211258.01	KATHRYN ANN WEBB	3/31/2008	HOOD	2396	26	7515
TX	HOOD	TX2211258.02	ROBERT LEE WEBB	3/31/2008	HOOD	2403	32	9186
TX	HOOD	TX2211260.01	LINDA GAIL CONNER	4/5/2008	HOOD	2397	441	7846
TX	HOOD	TX2211260.02	RICHARD J CONNER	4/5/2008	HOOD	2397	443	7847
TX	HOOD	TX2211261.01	KENT MOORE ET UX	4/18/2008	HOOD	2397	429	7841
TX	HOOD	TX2211261.02	GEORGE M MOORE III	4/18/2008	HOOD	2397	432	7842
TX	HOOD	TX2211261.03	GWENDOLYN CANNON MOORE	4/18/2008	HOOD	2403	39	9189
TX	HOOD	TX2211262.01	DEBORAH L NORTON	4/17/2008	HOOD	2414	228	11728
TX	HOOD	TX2211262.02	REBECCA L MANDLI	4/17/2008	HOOD	2414	230	11729
TX	HOOD	TX2211262.03	VICTORIA A TOMPKINS	4/17/2008	HOOD	2414	226	11727
TX	HOOD	TX2211262.04	JACKIE J TOMPKINS	4/23/2008	HOOD	2414	283	11754
TX	HOOD	TX2211262.05	CONNIE E LINDSTROM	4/28/2008	HOOD	2414	285	11755
TX	HOOD	TX2211262.06	CHARLOTTE D CHRISTIAN	5/2/2008	HOOD	2414	279	11752
TX	HOOD	TX2211262.07	DALE E TOMPKINS	4/29/2008	HOOD	2414	281	11753
TX	HOOD	TX2211262.08	LAURENCE H LANCASTER ET UX	8/25/2008	HOOD	2437	278	17315
TX	HOOD	TX2211262.09	SUSAN E LAKE ET VIR	4/17/2008	HOOD	2433	331	16313
TX	HOOD	TX2211263.00	FIRST FINANCIAL BANK N A	4/16/2008	HOOD	2412	690	11366
TX	HOOD	TX2211263.00	FIRST FINANCIAL BANK N A	4/16/2008
TX	HOOD	TX2211264.00	US POSTAL SERVICE	6/4/2008	HOOD	2408	490	10425
TX	HOOD	TX2211265.00	CORP OF EPISCOPAL DIOCESE	2/12/2008	HOOD	2405	742	9837
TX	HOOD	TX2211266.00	SNJ BUILDERS DBA S MILLER	4/24/2008	HOOD	2397	435	7843
TX	HOOD	TX2211270.00	JOE K OVERSTREET ET UX	4/21/2008	HOOD	2403	36	9188
TX	HOOD	TX2211273.01	ALICE NEU HAMPTON	5/7/2008	HOOD	2403	47	9192
TX	HOOD	TX2211273.02	JAMES R MCLELLAN ET UX	5/7/2008	HOOD	2433	307	16303
TX	HOOD	TX2211276.00	J C WARDEN ET UX	5/1/2008	HOOD	2403	34	9187
TX	HOOD	TX2211278.00	FRANCISCO J SORIA ET UX	4/13/2008	HOOD	2403	52	9194
TX	HOOD	TX2211281.00	LENDY J GREGORY ET UX	3/5/2008	HOOD	2405	680	9811
TX	HOOD	TX2211282.00	FRED M WOOD	5/20/2008	HOOD	2414	224	11726
TX	HOOD	TX2211286.00	DAVID M JONES ET UX	5/23/2008	HOOD	2403	216	9244
TX	HOOD	TX2211287.00	TIMMIE LEE HAYWORTH ET UX	5/23/2008	HOOD	2403	214	9243
TX	HOOD	TX2211288.00	JERRY D EICHLER ET UX	5/20/2008	HOOD	2405	692	9817
TX	HOOD	TX2211289.00	JOAN OLSON HANSON DBA OMEG	5/12/2008	HOOD	2408	488	10424
TX	HOOD	TX2211290.00	NORMA JEANNE GANZE	12/12/2007	HOOD	2408	498	10429
TX	HOOD	TX2211294.01	PATSY RAY HEWLETT	5/23/2008	HOOD	2403	208	9240
TX	HOOD	TX2211294.02	KRESSIE K SHIREY	5/23/2008	HOOD	2403	212	9242
TX	HOOD	TX2211294.03	TIMMIE LEE HAYWORTH	5/23/2008	HOOD	2403	206	9239
TX	HOOD	TX2211294.04	DENNA R JONES	5/23/2008	HOOD	2403	210	9241
TX	HOOD	TX2211298.00	ACTON PROPERTIES LLC	5/7/2008	HOOD	2414	241	11734
TX	HOOD	TX2211299.00	ROBBIE E HAYWORTH	6/9/2008	HOOD	2404	210	9469
TX	HOOD	TX2211300.00	DONALD L MACFARLANE / VLB	12/6/2001	HOOD	1815	49	3909
TX	HOOD	TX2211301.00	CROSSROADS 167 PARTNERS	6/14/2008	HOOD	2414	305	11765
TX	HOOD	TX2211302.00	JAMES LYNDELL SMITH ET UX	3/31/2008	HOOD	2414	264	11745
TX	HOOD	TX2211306.00	TOMMY D GWINN ET UX	8/18/2006	HOOD	2271	340	1738
TX	HOOD	TX2211307.00	MOHAMMAD ABOUTALEBI ET AL	6/30/2006	HOOD	2219	242	13041
TX	HOOD	TX2211308.00	JAMES MORRISON ET UX	6/1/2006	HOOD	2211	121	11141
TX	HOOD	TX2211309.00	STEVE MITCHAM ET AL	5/14/2006	HOOD	2201	654	9229
TX	HOOD	TX2211310.00	CHARLES STRICKLAND ET UX	6/10/2006	HOOD	2210	355	10966
TX	HOOD	TX2211313.00	D&G FREEHOLD LTD	5/22/2008	HOOD	2414	217	11723
TX	HOOD	TX2211314.00	RICHARD J HOLEMAN	5/29/2008	HOOD	2433	270	16287
TX	HOOD	TX2211315.00	NATHAN BROWNLEE ET AL	12/12/2007	HOOD	2419	173	12951
TX	HOOD	TX2211316.00	STEPHANIE L MORGAN	12/9/2007	HOOD	2414	274	11750
TX	HOOD	TX2211317.00	DENBEEK PROPERTIES LTD	7/7/2008	HOOD	2419	158	12944
TX	HOOD	TX2211319.00	MONARCH UTILITIES I, LP	4/21/2008	HOOD	2419	155	12943
TX	HOOD	TX2211320.00	JESSICA TAYLOR	6/25/2008	HOOD	2419	181	12954
TX	HOOD	TX2211321.99	TGA SOD LP	7/17/2008	HOOD	2414	162	11707
TX	HOOD	TX2211323.00	BEACON REAL ESTATE HOLDING	6/26/2008	HOOD	2431	443	15856
TX	HOOD	TX2211325.00	BETTY SUE KILLION	5/19/2008	HOOD	2415	874	12170
TX	HOOD	TX2211326.01	SUNCHASE DEVELOPMENT CO	7/30/2008	HOOD	2418	285	12725
TX	HOOD	TX2211326.02	MERILYN EVANS	11/5/2008	HOOD	2446	825	19632
TX	HOOD	TX2211329.00	NUBBIN RIDGE CEMETERY	8/5/2008	HOOD	2418	973	12897
TX	HOOD	TX2211332.00	MERRITHEW AND MERRITHEW	6/2/2008	HOOD	2429	856	15417
TX	HOOD	TX2211338.00	JOAN ALICE PHILLIPS	8/19/2008	HOOD	2433	281	16291
TX	HOOD	TX2211339.00	IKE SAWYER ET UX	8/5/2008	HOOD	2429	854	15416
TX	HOOD	TX2211341.00	ROBERT A PAVELICK ET UX	7/12/2008	HOOD	2429	900	15439
TX	HOOD	TX2211342.00	STEVEN J HAINES ET UX	3/5/2008	HOOD	2429	880	15429
TX	HOOD	TX2211344.00	DONNA KAY BAKER ET VIR	8/5/2008	HOOD	2429	842	15411
TX	HOOD	TX2211347.00	ST TX M-109291	7/22/2008	HOOD
TX	HOOD	TX2211348.00	ST TX M-109290	7/22/2008	HOOD
TX	HOOD	TX2211349.01	JOE T CULP ET UX	8/19/2008	HOOD	2433	283	16292
TX	HOOD	TX2211350.00	BKR CONTRACTORS GROUP, LP	3/17/2008	HOOD	2433	297	16299
TX	HOOD	TX2211351.01	FREELAN MABERY	8/14/2008	HOOD	2433	320	16308
TX	HOOD	TX2211351.02	THE MABERY TRUST	8/14/2008	HOOD	2433	293	16297
TX	HOOD	TX2211352.01	GARY W KINSLOW ET UX	8/25/2008	HOOD	2433	302	16301
TX	HOOD	TX2211353.00	KENNETH G NICKELL ET UX	4/20/2008	HOOD	2433	304	16302
TX	HOOD	TX2211355.00	D R STONE & P S COPELAND	8/28/2008	HOOD	2433	289	16295
TX	HOOD	TX2211356.00	RONALD P BERLIN ET UX	9/23/2008	HOOD	2430	498	15608
TX	HOOD	TX2211357.00	THURMAN DUNN	8/28/2008	HOOD	2434	980	16753
TX	HOOD	TX2211364.00	LEON NEAT ET UX	9/1/2008	HOOD	2435	6	16763
TX	HOOD	TX2211369.00	KERRY E COOPER ET UX	9/1/2008	HOOD	2442	915	18668
TX	HOOD	TX2211371.00	JERRY P ANDERSON ET UX	9/1/2008	HOOD	2437	265	17309
TX	HOOD	TX2211373.00	HOOD COUNTY COMMISSIONERS	9/2/2008	HOOD	2437	282	17317
TX	HOOD	TX2211376.00	JOSE G LOPEZ ET UX	9/30/2008	HOOD	2448	992	20106
TX	HOOD	TX2211377.00	PATTY TRAMMELL	9/3/2008	HOOD	2449	8	20112
TX	HOOD	TX2211378.00	KATRINA MCFADDEN	9/13/2008	HOOD	2436	451	17127
TX	HOOD	TX2211380.00	JOSE AVALOS ET UX	9/1/2008	HOOD	2463	528	3226
TX	HOOD	TX2211383.00	DONALD R TATLOCK ET UX	9/10/2008	HOOD	2449	6	20111
TX	HOOD	TX2211385.00	DANIEL C FAUBER ET UX	9/1/2008	HOOD	2449	31	20122
TX	HOOD	TX2211386.00	TIMOTHY P WHITE	9/23/2008	HOOD	2449	18	20116
TX	HOOD	TX2211388.00	ACTON MUNICIPAL UTILITY DI	9/1/2008	HOOD	2442	849	18641
TX	HOOD	TX2211393.94	RANDY J DEYOUNG ET UX	3/12/2013	HOOD			2013-0005271
TX	HOOD	TX2211396.01	CECIL M PETERS	11/11/2008	HOOD	2442	992	18694
TX	HOOD	TX2211396.02	FIRST NATL BANK OF GRANBURY	7/29/2008	HOOD	2429	892	15435
TX	HOOD	TX2211396.02	FIRST NATL BANK OF GRANBURY	7/29/2008
TX	HOOD	TX2211398.00	JOHN E PRUITT ET UX	10/24/2008	HOOD	2449	52	20130
TX	HOOD	TX2211398.00	JOHN E PRUITT ET UX	10/24/2008
TX	HOOD	TX2211399.00	CONNIE HOOD	9/23/2008	HOOD	2442	902	18664
TX	HOOD	TX2211400.00	TBL VENTURES LLC	8/27/2008	HOOD	2456	801	1798
TX	HOOD	TX2211401.01	DAVID E SHAFFER ET UX	8/27/2008	HOOD	2442	896	18661
TX	HOOD	TX2211401.02	RENALDO M GAMUNDI	8/27/2008	HOOD	2446	837	19636
TX	HOOD	TX2211402.00	LOU ANN LANGFORD	11/15/2008	HOOD	2446 AND 2446	964 AND 960	19670 AND 19668
TX	HOOD	TX2211403.00	LOU ANN LANGFORD	11/15/2008	HOOD	2446	962	19669
TX	HOOD	TX2211407.00	ROY G WESSON ET UX	11/14/2008	HOOD	2446	788	19621
TX	HOOD	TX2211408.00	ACTON UNITED METHODIST	11/6/2008	HOOD	2442	957	18683
TX	HOOD	TX2211409.00	JOSE GUZMAN ET UX	11/15/2008	HOOD	2442	943	18678
TX	HOOD	TX2211410.00	RICHARD W MANDEL JR ET UX	11/15/2008	HOOD	2442	940	18677
TX	HOOD	TX2211411.00	JIM BURNS ET UX	11/12/2008	HOOD	2442	949	18680
TX	HOOD	TX2211412.00	JOSE NOYOLA ET UX	11/15/2008	HOOD	2442	921	18671
TX	HOOD	TX2211413.00	JOSE SANTOS ORELLANA ET UX	11/15/2008	HOOD	2442	924	18672
TX	HOOD	TX2211414.00	SANDRA E DAUGHERTY	11/15/2008	HOOD	2442	927	18673
TX	HOOD	TX2211415.00	JOHN CAREY	11/15/2008	HOOD	2442	930	18674
TX	HOOD	TX2211416.00	RONALD CHRIS SINN	11/12/2008	HOOD	2442	933	18675
TX	HOOD	TX2211417.00	MARIA HERNANDEZ	11/15/2008	HOOD	2442	980	18690
TX	HOOD	TX2211418.00	KEVIN JACKSON ET UX	11/14/2008	HOOD	2446	782	19619
TX	HOOD	TX2211419.00	DEBBIE-LOU W HANSON	11/12/2008	HOOD	2442	989	18693
TX	HOOD	TX2211420.00	ANTONIO G MOJICA ET UX	11/15/2008	HOOD	2442	986	18692
TX	HOOD	TX2211421.00	JOSE SOLIS	11/15/2008	HOOD	2442	983	18691
TX	HOOD	TX2211422.00	MICHAEL KEVIN MCCURTAIN ET	11/15/2008	HOOD	2442	977	18689
TX	HOOD	TX2211423.00	STEVE E WILSON ET UX	11/15/2008	HOOD	2442	974	18688
TX	HOOD	TX2211424.00	GABRIELE HEADING	11/15/2008	HOOD	2442	971	18687
TX	HOOD	TX2211425.00	WILMA ANN WALKER	11/15/2008	HOOD	2442	954	18682
TX	HOOD	TX2211426.00	JOSE MOJICA ET UX	11/15/2008	HOOD	2442	968	18686
TX	HOOD	TX2211427.00	PATRICIA JONES	11/15/2008	HOOD	2442	946	18679
TX	HOOD	TX2211428.00	FRANCISCO ESCALON ET UX	11/15/2008	HOOD	2442	937	18676
TX	HOOD	TX2211429.00	CHRISTY M LANGSTON	11/15/2008	HOOD	2442	965	18685
TX	HOOD	TX2211430.00	KATHRYN SAVAGE	11/15/2008	HOOD	2442	962	18684
TX	HOOD	TX2211431.00	CHRISTY ANN BARCLAY	11/15/2008	HOOD	2446	861	19644
TX	HOOD	TX2211432.00	GEORGE E BARLOW	11/15/2008	HOOD	2446	854	19642
TX	HOOD	TX2211433.00	ISMAEL L MARTINEZ ET UX	11/20/2008	HOOD	2446	851	19641
TX	HOOD	TX2211434.00	GLORIA ESPINOZA	11/15/2008	HOOD	2446	839	19637
TX	HOOD	TX2211435.00	EMIGDIO TRUJILLO CABRERA	11/15/2008	HOOD	2446	842	19638
TX	HOOD	TX2211436.00	DANIEL R ROHDE ET UX	9/24/2008	HOOD	2446	800	19625
TX	HOOD	TX2211437.00	JOHN C TIBBS ET UX	11/18/2008	HOOD	2446	845	19639
TX	HOOD	TX2211438.00	LEO STEFANSKI	11/15/2008	HOOD	2446	864	19645
TX	HOOD	TX2211439.00	MANUEL MARTINEZ ET UX	11/24/2008	HOOD	2446	847	19640
TX	HOOD	TX2211440.00	HUGH MYERS ET UX	11/15/2008	HOOD	2446	803	19626
TX	HOOD	TX2211441.00	RAUL R VILLEGAS	11/15/2008	HOOD	2446	857	19643
TX	HOOD	TX2211442.00	GENE W HAND ET UX	11/15/2008	HOOD	2446	814	19629
TX	HOOD	TX2211443.00	TROY MONTGOMERY ET UX	11/15/2008	HOOD	2446	817	19630
TX	HOOD	TX2211444.00	ANTONIO TREJO ET UX	11/15/2008	HOOD	2446	828	19633
TX	HOOD	TX2211445.00	RUTILIO HERNANDEZ ET UX	11/15/2008	HOOD	2446	821	19631
TX	HOOD	TX2211446.00	ROBERT D STRINGER ET UX	11/15/2008	HOOD	2446	808	19628
TX	HOOD	TX2211447.00	CINDY LU WILKERSON	11/15/2008	HOOD	2446	785	19620
TX	HOOD	TX2211448.00	PATRICIA SHARP	11/15/2008	HOOD	2446	791	19622
TX	HOOD	TX2211449.00	ROBERT WHITEHEAD ET UX	11/15/2008	HOOD	2446	794	19623
TX	HOOD	TX2211450.00	LUCIO CABRERA TRUJILLO	11/15/2008	HOOD	2446	777	19617
TX	HOOD	TX2211451.00	CHEYENNE SMITH	11/15/2008	HOOD	2446	832	19634
TX	HOOD	TX2211452.01	ALAN HORNER	11/12/2008	HOOD	2446	893	19654
TX	HOOD	TX2211453.01	SHIRLEY J MCCONAL	11/12/2008	HOOD	2446	904	19657
TX	HOOD	TX2211453.02	BILL C JAMES	11/12/2008	HOOD	2449	43	20127
TX	HOOD	TX2211454.01	WADE RAILSBACK	11/12/2008	HOOD	2446	797	19624
TX	HOOD	TX2211454.02	MARSHALL T VOSE JR ET UX	1/12/2009	HOOD	2461	518	2805
TX	HOOD	TX2211455.00	MALONIE FLORES ET VIR	11/15/2008	HOOD	2446	890	19653
TX	HOOD	TX2211456.00	ERIN LINNEY ET VIR	11/19/2008	HOOD	2446	868	19646
TX	HOOD	TX2211457.00	GRACIELA CAZARES	11/15/2008	HOOD	2446	871	19647
TX	HOOD	TX2211458.00	DAVID HENSEL ET UX	11/24/2008	HOOD	2446	874	19648
TX	HOOD	TX2211459.00	WILLIAM W STONE JR ET UX	11/15/2008	HOOD	2446	877	19649
TX	HOOD	TX2211460.00	M CABRERA & T VELAZQUEZ	11/15/2008	HOOD	2446	880	19650
TX	HOOD	TX2211461.00	CHARLES D PEACOCK ET UX	12/1/2008	HOOD	2446	883	19651
TX	HOOD	TX2211462.00	WILLIAM N HOFMANN ET UX	11/22/2008	HOOD	2446	886	19652
TX	HOOD	TX2211463.00	LEPEL DARRELL ALEXANDER	11/15/2008	HOOD	2446	900	19656
TX	HOOD	TX2211464.00	SHAMROCK BUILDERS INC	12/3/2008	HOOD	2449	49	20129
TX	HOOD	TX2211465.00	RONALD WRIGHT ET UX	10/31/2008	HOOD	2444	134	18943
TX	HOOD	TX2211466.00	JESSICA M OZUNA	12/4/2008	HOOD	2449	40	20126
TX	HOOD	TX2211467.00	LUCIO M GAMEZ ET UX	12/4/2008	HOOD	2449	46	20128
TX	HOOD	TX2211468.00	JIM D BENWARE ET UX	11/28/2008	HOOD	2463	524	3225
TX	HOOD	TX2211469.00	JAMES C KAHRS	12/1/2008	HOOD	2463	549	3234
TX	HOOD	TX2211470.00	WRILEY & LINDA STARK TRUST	12/5/2008	HOOD	2456	818	1803
TX	HOOD	TX2211471.00	LAKE GRANBURY POST NO 491	12/2/2008	HOOD	2461	508	2802
TX	HOOD	TX2211472.00	AMERICAN LEGION AUX 491	12/2/2008	HOOD	2456	814	1802
TX	HOOD	TX2211473.00	WINSTON T BOOKER JR AIF	10/20/2008	HOOD	2456	807	1800
TX	HOOD	TX2211474.00	BERTA GORNEY AIF WILKINSON	12/9/2008	HOOD	2461	512	2803
TX	HOOD	TX2211475.00	RONNA COTTEN	11/15/2008	HOOD	2456	826	1805
TX	HOOD	TX2211476.00	EFRAIN CANTU	12/20/2008	HOOD	2456	833	1807
TX	HOOD	TX2211477.00	OSCAR ROBLEDO ET UX	12/12/2008	HOOD	2456	829	1806
TX	HOOD	TX2211478.00	MARIA DE JESUS SANCHEZ	12/10/2008	HOOD	2456	823	1804
TX	HOOD	TX2211479.00	RONALD RAY CHEYNE FAM TRST	12/5/2008	HOOD	2451	620	566
TX	HOOD	TX2211480.01	DANA PERRY	12/10/2008	HOOD	2461	525	2807
TX	HOOD	TX2211480.02	DAVID ZUNKER	12/10/2008	HOOD	2461	522	2806
TX	HOOD	TX2211482.00	FRANKLIN D RAMER	12/11/2008	HOOD	2463	534	3229
TX	HOOD	TX2211483.00	AUGUSTIN J ESPINOSA	12/19/2008	HOOD	2461	515	2804
TX	HOOD	TX2211484.00	MIGUEL TOVAR	12/15/2008	HOOD	2461	482	2794
TX	HOOD	TX2211485.00	BOB HARRIS OIL COMPANY	11/21/2008	HOOD	2451	618	565
TX	HOOD	TX2211486.00	HABITAT FOR HUMANITY HOOD	12/5/2008	HOOD	2461	473	2793
TX	HOOD	TX2211487.00	WOLF HOLLOW I LP	12/1/2008	HOOD	2451	79	410
TX	HOOD	TX2211488.00	MABLE ROE	12/15/2008	HOOD	2456	786	1793
TX	HOOD	TX2211489.00	COMANCHE INVESTMENTS INC	12/15/2008	HOOD	2458	780	2131
TX	HOOD	TX2211491.00	JAY JOHNSON ET AL	1/12/2009	HOOD	2451	759	597
TX	HOOD	TX2211493.00	ST TX M-108076	7/17/2007	HOOD
TX	HOOD	TX2211494.00	ST TX M-108075	7/17/2007	HOOD
TX	HOOD	TX2211495.00	ST TX M-108550	11/6/2007	HOOD
TX	HOOD	TX2211496.00	ST TX M-108270	9/18/2007	HOOD
TX	HOOD	TX2211497.00	JAMES S FRITZ ET UX	9/22/2008	HOOD	2462	511	2991
TX	HOOD	TX2211499.00	LARRY WHITE	12/21/2008	HOOD	2467	243	4069
TX	HOOD	TX2211500.00	EMMANUEL TOVAR ET UX	1/7/2009	HOOD	2456	804	1799
TX	HOOD	TX2211502.00	RAMIRO VILLEGAS ET UX	1/5/2009	HOOD	2456	810	1801
TX	HOOD	TX2211505.00	CYNTHIA A OLSON ET VIR	1/15/2009	HOOD	2456	792	1795
TX	HOOD	TX2211506.00	WILLIAM CALL ET UX	1/10/2009	HOOD	2454	706	1360
TX	HOOD	TX2211507.00	BARBARA L FACER	1/10/2009	HOOD	2454	709	1361
TX	HOOD	TX2211508.01	CANDY C WRIGHT	1/16/2009	HOOD	2461	505	2801
TX	HOOD	TX2211508.02	JUAN L ROMAN	1/16/2009	HOOD	2461	493	2797
TX	HOOD	TX2211510.00	PATRICIA MORTIMER	11/23/2008	HOOD	2463	545	3233
TX	HOOD	TX2211511.00	ROY G WESSON ET UX	1/21/2009	HOOD	2461	496	2798
TX	HOOD	TX2211512.00	ABEL HERNANDEZ ET UX	1/23/2009	HOOD	2461	499	2799
TX	HOOD	TX2211513.00	JORGE REBELES ET UX	1/28/2009	HOOD	2461	470	2792
TX	HOOD	TX2211514.00	TED ALLEN ET UX	1/10/2009	HOOD	2456	789	1794
TX	HOOD	TX2211519.00	DAULTON A THORP ET UX	12/31/2008	HOOD	2461	429	2779
TX	HOOD	TX2211520.00	JOSE GUADALUPE ROBLEDO ET	1/28/2009	HOOD	2461	502	2800
TX	HOOD	TX2211521.00	DAVID WAYNE FULKERSIN ET U	1/28/2009	HOOD	2461	490	2796
TX	HOOD	TX2211522.00	RANDALL G OEHLER	1/13/2009	HOOD	2461	486	2795
TX	HOOD	TX2211524.00	GRANBURY 187 RIVER TRAILS	2/4/2009	HOOD	2467	241	4068
TX	HOOD	TX2211525.01	JOSE CRUZ TOVAR	1/13/2009	HOOD	2467	254	4073
TX	HOOD	TX2211525.02	MARIA VALLE ESPINOSA	6/29/2009	HOOD	2493	776	10040
TX	HOOD	TX2211526.00	ANTONIO SANDOVAL ET UX	1/15/2009	HOOD	2463	492	3214
TX	HOOD	TX2211527.00	SANDRA J CONGER	2/9/2009	HOOD	2467	260	4075
TX	HOOD	TX2211528.00	LEXA NORTHINGTON STECKO	1/22/2009	HOOD	2461	438	2782
TX	HOOD	TX2211529.00	HALEY L DYER JR ET UX	1/13/2009	HOOD	2467	246	4070
TX	HOOD	TX2211531.00	PATRICIA ANN LOPEZ	2/13/2009	HOOD	2463	539	3231
TX	HOOD	TX2211532.01	VICKIE J RICE	1/28/2009	HOOD	2461	452	2786
TX	HOOD	TX2211532.02	LINDA S FORSYTHE ET VIR	1/28/2009	HOOD	2467	232	4065
TX	HOOD	TX2211532.03	JANET A SCHUMP	1/28/2009	HOOD	2469	658	4595
TX	HOOD	TX2211533.00	AMADOR CASTILLO JR	1/14/2009	HOOD	2461	467	2791
TX	HOOD	TX2211534.00	RICHARD L HATTOX	1/27/2009	HOOD	2461	455	2787
TX	HOOD	TX2211535.00	CHARLOTTE GARRETT	1/27/2009	HOOD	2463	521	3224
TX	HOOD	TX2211536.00	ROBERT ALLEN THOMAS	2/12/2009	HOOD	2461	461	2789
TX	HOOD	TX2211537.00	GREG W COPELAND ET AL	1/20/2009	HOOD	2461	441	2783
TX	HOOD	TX2211538.00	WESLEY E HENRY	1/20/2009	HOOD	2461	444	2784
TX	HOOD	TX2211540.00	LORI SPENCE	1/12/2009	HOOD	2463	480	3210
TX	HOOD	TX2211541.00	SHERI BREWER	2/10/2009	HOOD	2467	257	4074
TX	HOOD	TX2211542.00	CRAJ LTD	1/13/2009	HOOD	2463	489	3213
TX	HOOD	TX2211543.00	DONALD YOCUM BRUNDAGE ET UX	1/20/2009	HOOD	2463	486	3212
TX	HOOD	TX2211544.00	NOLAN TODD GIBSON ET UX	2/6/2009	HOOD	2460	730	2641
TX	HOOD	TX2211546.00	KELLY MCCURTAIN	3/4/2009	HOOD	2469	670	4599
TX	HOOD	TX2211547.00	LAVONNE ANN MOORE	2/20/2009	HOOD	2469	667	4598
TX	HOOD	TX2211548.00	SHERRY STONE NEAL	2/20/2009	HOOD	2469	664	4597
TX	HOOD	TX2211549.00	MICHAEL LYNN PORTER	1/20/2009	HOOD	2469	676	4601
TX	HOOD	TX2211551.00	JOSE C CORTES	2/28/2009	HOOD	2469	661	4596
TX	HOOD	TX2211553.00	CHRISTOPHER M BROWN ET UX	1/27/2009	HOOD	2469	643	4590
TX	HOOD	TX2211555.00	EDDIE PARSONS ET UX	2/12/2009	HOOD	2467	263	4076
TX	HOOD	TX2211558.00	SILVIA NORA HERNANDEZ	3/5/2009	HOOD	2469	682	4603
TX	HOOD	TX2211559.00	LARRY WAYNE BISHOP ET UX	1/27/2009	HOOD	2469	688	4605
TX	HOOD	TX2211560.00	JIMMY LEE GRIMES ET UX	2/24/2009	HOOD	2469	636	4588
TX	HOOD	TX2211561.01	VICTORIA OVERTON	2/19/2009	HOOD	2472	655	5251
TX	HOOD	TX2211561.02	KENNETH MICHELS	3/7/2009	HOOD	2472	658	5252
TX	HOOD	TX2211562.01	SHELIA J YOUNGBLOOD	2/17/2009	HOOD	2472	673	5257
TX	HOOD	TX2211562.02	ELIZABETH BREWER	2/17/2009	HOOD	2472	679	5259
TX	HOOD	TX2211562.03	BRENDA LESLY	2/17/2009	HOOD	2472	676	5258
TX	HOOD	TX2211563.00	LANTZ VINZENS	2/24/2009	HOOD	2469	685	4604
TX	HOOD	TX2211565.00	SALVADOR E CASTILLO	3/20/2009	HOOD	2472	652	5250
TX	HOOD	TX2211566.00	HAROLD E DURHAM ET UX	1/27/2009	HOOD	2472	637	5244
TX	HOOD	TX2211567.00	TODD J SHEPHERD ET UX	1/26/2009	HOOD	2472	661	5253
TX	HOOD	TX2211568.00	CARRIE LYTLE ET VIR	3/5/2009	HOOD	2472	640	5245
TX	HOOD	TX2211569.00	RAMIRO BAUTISTA ET UX	3/12/2009	HOOD	2472	685	5261
TX	HOOD	TX2211571.00	ARCHIE MCCOY EXE GOULD EST	1/16/2009	HOOD	2474	123	5612
TX	HOOD	TX2211572.00	RENEA K LEE	3/16/2009	HOOD	2474	115	5609
TX	HOOD	TX2211573.00	JIMMY D GLENN	3/10/2009	HOOD	2474	126	5613
TX	HOOD	TX2211578.00	TIM CANTRELL	4/16/2009	HOOD	2481	895	7308
TX	HOOD	TX2211579.00	MURLE BLASINGAME ET UX	4/16/2009	HOOD	2481	918	7317
TX	HOOD	TX2211581.01	LINDA LANEY	5/5/2009	HOOD	2485	622	8135
TX	HOOD	TX2211581.02	NILA KAYLENE COUNSELLOR	5/5/2009	HOOD	2485	619	8134
TX	HOOD	TX2211581.03	CARL DAVID LANEY	5/5/2009	HOOD	2485	628	8137
TX	HOOD	TX2211581.04	JIMMY RAY LANEY	5/5/2009	HOOD	2485	625	8136
TX	HOOD	TX2211582.00	KIRK MAYES ET UX	4/13/2009	HOOD	2479	833	6813
TX	HOOD	TX2211583.00	PATRICIA A CASAS	5/13/2009	HOOD	2485	649	8146
TX	HOOD	TX2211584.00	LEAH A BUCHER	4/30/2009	HOOD	2485	639	8142
TX	HOOD	TX2211587.00	HAROLD R HOLLOWAY ET UX	5/5/2009	HOOD	2485	659	8149
TX	HOOD	TX2211588.00	ANTHONY D BOYDSTON	3/27/2009	HOOD	2485	654	8148
TX	HOOD	TX2211589.00	CHARLES YOUNGBLOOD ET UX	4/8/2009	HOOD	2481	946	7326
TX	HOOD	TX2211591.00	KRISTOPHER D GARRISON ET U	4/16/2009	HOOD	2485	689	8159
TX	HOOD	TX2211592.00	FIVE DCDHC INVESTMENTS LP	5/20/2009	HOOD	2485	669	8152
TX	HOOD	TX2211593.00	LARRY DICK	5/20/2009	HOOD	2481	523	7220
TX	HOOD	TX2211597.01	ARCHIE JOE WHEAT	6/16/2009	HOOD	2486	915	8468
TX	HOOD	TX2211597.02	DONNA GLENN BAKER	6/16/2009	HOOD	2486	918	8469
TX	HOOD	TX2211597.03	JIMMY D GLENN	6/16/2009	HOOD	2487	38	8499
TX	HOOD	TX2211598.00	JERRY SHUTTLESWORTH	2/3/2009	HOOD	2488	132	8728
TX	HOOD	TX2211599.00	MARSHALL LANEY	5/13/2009	HOOD	2488	105	8718
TX	HOOD	TX2211600.00	LEON T CABRERA ET UX	4/16/2009	HOOD	2486	923	8471
TX	HOOD	TX2211601.00	HOOD COUNTY COMMISSIONERS	4/23/2009	HOOD	2488 AND 2488	0128 AND 0296	08727 AND 08782
TX	HOOD	TX2211602.00	ST TX M-109902	12/16/2008	HOOD
TX	HOOD	TX2211603.00	MONARCH UTILITIES ILP	6/8/2009	HOOD	2496	426	10656
TX	HOOD	TX2211607.01	FREDDIE LEON WESLEY	7/9/2009	HOOD	2498	116	11073
TX	HOOD	TX2211607.02	DONNA D WESLEY	7/9/2009	HOOD	2501	479	11877
TX	HOOD	TX2211612.00	MATTHEW A SCHOESSOW	8/8/2009	HOOD	2503	957	12525
TX	HOOD	TX2211614.01	CHARLES P WATTS ET AL	8/10/2009	HOOD	2503	964	12527
TX	HOOD	TX2211614.02	HELEN H DURANT	8/10/2009	HOOD	2503	960	12526
TX	HOOD	TX2211615.00	CRYKAY LLC	8/20/2009	HOOD	2503	968	12528
TX	HOOD	TX2211617.99	ALICE WILLEFORD ET AL	9/22/2009	HOOD	2524	386	424
TX	HOOD	TX2211619.00	GERALD C BROESCHE ET UX	8/8/2009	HOOD	2506	508	13174
TX	HOOD	TX2211622.00	HABITAT FOR HUMANITY	9/28/2009	HOOD	2509	613	13955
TX	HOOD	TX2211623.00	CHARO INC	10/1/2009	HOOD	2514	696	15203
TX	HOOD	TX2211624.00	CHARO INC	10/2/2009	HOOD	2514	684	15199
TX	HOOD	TX2211625.00	PEI-I HUANG MULCAHY	8/12/2009	HOOD	2509	625	13960
TX	HOOD	TX2211626.00	FRANCISCO MARTINEZ ET UX	8/12/2009	HOOD	2509	622	13959
TX	HOOD	TX2211627.00	ROD FINCH ET UX	9/20/2009	HOOD	2514	664	15191
TX	HOOD	TX2211629.00	MELITON TORRES ET UX	9/23/2009	HOOD	2514	679	15197
TX	HOOD	TX2211630.00	WILLIAM L BOOTH ET UX	9/20/2009	HOOD	2514	693	15202
TX	HOOD	TX2211632.00	JERIME L JOHNSTON ET UX	8/16/2009	HOOD	2517	770	15942
TX	HOOD	TX2211634.00	MERILYN EVANS 2006 REV TST	9/20/2009	HOOD	2514	659	15189
TX	HOOD	TX2211635.00	BILLY C MITCHELL ET UX	9/20/2009	HOOD	2514	690	15201
TX	HOOD	TX2211638.00	ROBERT E BROOKS ET UX	11/9/2009	HOOD	2517	788	15950
TX	HOOD	TX2211639.01	FAWZY S SEDRAK ET UX	10/10/2009	HOOD	2517	830	15971
TX	HOOD	TX2211639.02	AMIR S IBRAHIM ET UX	10/10/2009	HOOD	2517	828	15970
TX	HOOD	TX2211640.00	TERRY D SAVAGE	9/20/2009	HOOD	2517	754	15937
TX	HOOD	TX2211642.00	LEA ANN HAYES ET VIR	12/7/2009	HOOD	2519	579	16451
TX	HOOD	TX2211644.00	WAYNE WIENECKE ET UX	11/17/2009	HOOD	2520	798	16766
TX	HOOD	TX2211649.00	JUSRYN COMPANY INC ET AL	1/27/2010	HOOD	2529	595	1683
TX	HOOD	TX2211650.01	JERRY A GOIN	1/11/2010	HOOD	2528	900	1526
TX	HOOD	TX2211650.02	CYNTHIA ANN CRAIG MCGEORGE	6/15/2012	HOOD			2012-0007380
TX	HOOD	TX2211650.03	DENISE NEGLAY MONTEAGUDO	6/15/2012	HOOD			2012-0007379
TX	HOOD	TX2211650.04	ROBERT KELLY CRAIG	6/15/2012	HOOD			2012-0007381
TX	HOOD	TX2211651.00	CHRISTOPHER M BARNES	2/3/2010	HOOD	2528	891	1523
TX	HOOD	TX2211652.00	MARGARET KENNEDY ET VIR	2/4/2010	HOOD	2528	897	1525
TX	HOOD	TX2211653.00	ROQUE MAGALLANES LUJAN ET UX	2/3/2010	HOOD	2528	894	1524
TX	HOOD	TX2211654.00	DAVID TORRES ET UX	1/6/2010	HOOD	2531	178	2053
TX	HOOD	TX2211657.00	DOUGLAS J AIKEN ET UX	2/16/2010	HOOD	2531	172	2051
TX	HOOD	TX2211659.01	LYNDELL RAY LOCKETT ET UX	2/24/2010	HOOD	2531	599	2160
TX	HOOD	TX2211659.01	LYNDELL RAY LOCKETT ET UX	2/24/2010
TX	HOOD	TX2211659.02	ALTON LEE LOCKETT ET UX	2/24/2010	HOOD	2531	596	2159
TX	HOOD	TX2211660.00	DAMIEN MARTINEZ ET UX	2/1/2010	HOOD	2534	383	2819
TX	HOOD	TX2211664.00	SHIRLEY JOHNSON	3/16/2010	HOOD	2535	378	3085
TX	HOOD	TX2211666.00	MICHAEL G TAYLOR ET UX	3/10/2010	HOOD	2535	440	3112
TX	HOOD	TX2211667.00	MICHAEL L READY ET AL	3/5/2010	HOOD	2535	443	3113
TX	HOOD	TX2211668.00	BARBARA YOHNER	2/22/2010	HOOD	2535	449	3115
TX	HOOD	TX2211669.00	DARLA SUE LANKFORD ET VIR	3/8/2010	HOOD	2538	480	3816
TX	HOOD	TX2211670.00	ROBERT LOWERY ET UX	3/22/2010	HOOD	2537	840	3678
TX	HOOD	TX2211675.00	CHAD TURMAN ET UX	4/8/2010	HOOD	2541	824	4631
TX	HOOD	TX2211677.99	MARY ELIZABETH ROLLINS	4/28/2010	HOOD	2548	530	6174
TX	HOOD	TX2211678.99	MARY ELIZABETH ROLLINS	4/28/2010	HOOD	2548	532	6175
TX	HOOD	TX2211680.00	EVAN ARLINGTON	4/23/2010	HOOD	2544	489	5262
TX	HOOD	TX2211681.00	ROBERT L STEELE JR ET UX	4/5/2010	HOOD	2544	486	5261
TX	HOOD	TX2211682.01	GLENN CORNELIUS	4/12/2010	HOOD	2547	638	5933
TX	HOOD	TX2211683.01	STANLEY WHITTUM ET UX	4/5/2010	HOOD			2010-0006523
TX	HOOD	TX2211683.02	CHRIS RUSSELL ET UX	8/4/2010	HOOD			2010-0010171
TX	HOOD	TX2211684.00	VICTOR CORTEZ SR & SANJUANAN	4/5/2010	HOOD	2545	953	5584
TX	HOOD	TX2211685.00	DOUGLAS A FLEMING ET UX	4/20/2010	HOOD	2545	950	5583
TX	HOOD	TX2211686.00	BILLY D PENNINGTON ET UX	4/30/2010	HOOD	2545	977	5593
TX	HOOD	TX2211687.00	RAYMOND D ANDERSEN ET UX	5/19/2010	HOOD			2010-0006522
TX	HOOD	TX2211688.00	KELLY ANN SWOPE	4/28/2010	HOOD			2010-0006521
TX	HOOD	TX2211689.00	JOHN ALLEN ET UX	5/14/2010	HOOD			2010-0006430
TX	HOOD	TX2211690.00	NORBERT R SMITH ET UX	4/5/2010	HOOD			2010-0006431
TX	HOOD	TX2211695.00	LLM MINERALS LP	7/26/2010	HOOD			2010-0009891
TX	HOOD	TX2211696.00	LLM MINERALS LP	7/26/2010	HOOD			2010-0009892
TX	HOOD	TX2211698.00	CURTIS C ORTLOFF ET UX	7/16/2010	HOOD			2010-0009315
TX	HOOD	TX2211699.00	FREDRAL L ZIMMERMAN	6/8/2010	HOOD			2010-0009314
TX	HOOD	TX2211701.99	CHRISTY ELAINE CRYER	9/1/2010	HOOD			2011-0003701
TX	HOOD	TX2211703.00	BRENDA G SMITH	5/11/2010	HOOD			2010-0010674
TX	HOOD	TX2211705.00	ROB ROY HUGHITT	8/26/2010	HOOD			2010-0011461
TX	HOOD	TX2211707.01	JULIET K GRITZ	9/10/2010	HOOD			2010-0011459
TX	HOOD	TX2211707.02	MATTHEW R GRITZ	9/10/2010	HOOD			2010-0011458
TX	HOOD	TX2211708.00	JAMES M CHRISTOPHER ET UX	10/15/2010	HOOD			2010-0012221
TX	HOOD	TX2211709.01	J&L EXCAVATION INC DEF PEN PLN	10/14/2010	HOOD			2010-0012885
TX	HOOD	TX2211710.00	JO RUTH SANDEL	10/12/2010	HOOD			2010-0012884
TX	HOOD	TX2211711.00	JOHN GORDON BRITE II ET UX	11/16/2010	HOOD			2010-0013443
TX	HOOD	TX2211712.00	GILDA B WARREN	12/2/2010	HOOD			2011-0000839
TX	HOOD	TX2211717.99	DAN L. GRIFFIN ET UX	3/7/2011	HOOD			2011-0002699
TX	HOOD	TX2211719.00	RALPH VANCE COLLINS	3/4/2011	HOOD			2011-0003264
TX	HOOD	TX2211720.00	ROWENA ELAINE WEST	3/4/2011	HOOD			2011-0003266
TX	HOOD	TX2211721.00	EDWIN BLAINE COLLINS	3/4/2011	HOOD			2011-0003271
TX	HOOD	TX2211722.00	DOYLE GAROLD COLLINS	3/4/2011	HOOD			2011-0003270
TX	HOOD	TX2211723.00	ROWENA COLLINS	3/4/2011	HOOD			2011-0003265
TX	HOOD	TX2211724.01	NELLIE J BARKER	3/10/2011	HOOD			2011-0003269
TX	HOOD	TX2211724.02	SHARON E STEMBRIDGE ET VIR	2/28/2011	HOOD			2011-0003267
TX	HOOD	TX2211724.03	CHRISTA B GARRETT	2/28/2011	HOOD			2011-0003268
TX	HOOD	TX2211725.00	MICHAEL PHILLIPS ET UX	3/22/2011	HOOD			2011-0004517
TX	HOOD	TX2211726.00	PATRICIA GRIFFIN	3/22/2011	HOOD			2011-0004518
TX	HOOD	TX2211734.00	FRANK B MABERY ET UX	7/12/2011	HOOD			2011-0009215
TX	HOOD	TX2211736.01	PATSY MARIE GEE INDIV & TRUSTE	8/24/2011	HOOD			2011-0010319
TX	HOOD	TX2211736.02	FUN-N-SUN REALTY LTD	1/20/2012	HOOD			2012-0001735
TX	HOOD	TX2211737.00	TOOD DYSON ET UX	8/25/2011	HOOD			2011-0010593
TX	HOOD	TX2211738.01	DAVID FRANCIS & LINDA ANN RAFFA	10/19/2011	HOOD			2011-0011935
TX	HOOD	TX2211739.00	RICKEY DALE JERNIGAN ET UX	11/7/2011	HOOD			2011-0012451
TX	HOOD	TX2211740.00	JAMES B OLIVER ET UX	11/5/2011	HOOD			2011-0012914
TX	HOOD	TX2211741.00	VICKI LYNN NIVENS	10/13/2011	HOOD			2011-0013507
TX	HOOD	TX2211742.01	MAX EDWARD CROSS	12/14/2011	HOOD			2012-0000249
TX	HOOD	TX2211742.02	LORA JANE HILL	12/14/2011	HOOD			2012-0000250
TX	HOOD	TX2211742.03	TERESA YOUNG	12/14/2011	HOOD			2012-0000251
TX	HOOD	TX2211742.04	CHARLES CROSS	12/14/2011	HOOD			2012-0000252
TX	HOOD	TX2211743.01	ROBERT C HUDSON ET UX	1/11/2012	HOOD			2012-0001164
TX	HOOD	TX2211744.01	ROBERT L AND SANDRA GILMORE	2/1/2012	HOOD			2012-0001742
TX	HOOD	TX2211745.00	GEORGE O JOSEPH	1/27/2012	HOOD			2012-0001740
TX	HOOD	TX2211747.01	CLYDE DAVIS	1/11/2012	HOOD			2012-0001739
TX	HOOD	TX2211748.01	REBECCA A JEFFERS	1/16/2012	HOOD			2012-0001738
TX	HOOD	TX2211749.00	KARIN A HARRINGTON ET VIR	2/28/2012	HOOD			2012-0002214
TX	HOOD	TX2211750.00	ONE PRIME LP	3/7/2012	HOOD			2012-0002629
TX	HOOD	TX2211751.00	BERNARD ROYAL ROUX	1/18/2012	HOOD			2012-0002585
TX	HOOD	TX2211752.01	NANCY LAQUEY	1/11/2012	HOOD			2012-0002817
TX	HOOD	TX2211756.01	ASA YOUNGBLOOD	2/24/2012	HOOD			2012-0003783
TX	HOOD	TX2211756.02	MICHELLE ANGALYNN STANFORD	11/4/2014	HOOD			2015-0000668
TX	HOOD	TX2211757.01	RALPH T NANNY ET UX	3/27/2012	HOOD			2012-0003785
TX	HOOD	TX2211757.02	WENDALL A AND BEVERLY G HOLMES	5/2/2012	HOOD			2012-0005049
TX	HOOD	TX2211758.00	ROYCE SWAIM ET UX	4/12/2012	HOOD			2012-0003998
TX	HOOD	TX2211759.01	ARTHUR W HUDSON ET UX	4/10/2012	HOOD			2012-0004001
TX	HOOD	TX2211762.01	JOE SWAIM ET UX	4/12/2012	HOOD			2012-0004609
TX	HOOD	TX2211762.02	AMELIA WINIFRED CLEMENS ET VIR	7/1/2014	HOOD			2014-0006979
TX	HOOD	TX2211762.03	DR LEE E E PICARD ET VIR	7/1/2014	HOOD			2014-0006978
TX	HOOD	TX2211762.04	VONTILLA M WATSON INDIV & AIF	7/1/2014	HOOD			2014-0008767
TX	HOOD	TX2211762.05	EMMA LEA BUCK WRIGHT	7/1/2014	HOOD			2014-0008768
TX	HOOD	TX2211763.00	DANNY LEE AND KELLY DENISE BRILEY	4/13/2012	HOOD			2012-0004595
TX	HOOD	TX2211764.04	BRYAN JACKS	4/18/2012	HOOD			2012-0005050
TX	HOOD	TX2211764.06	ROBERT L GILMORE ET UX	4/9/2014	HOOD			2014-0004124
TX	HOOD	TX2211764.07	LOIS ALLAINE WARD	12/10/2014	HOOD			2015-0002327
TX	HOOD	TX2211767.17	WARREN LEE UNDERWOOD #57245-097	4/20/2012	HOOD			2012-0006391
TX	HOOD	TX2211768.00	O'FARRELL AND MYRNA THOMPSON REV TRUST	4/25/2012	HOOD			2012-0004853
TX	HOOD	TX2211769.01	SCOT JAY AND KAY DUBE	4/12/2012	HOOD			2012-0005051
TX	HOOD	TX2211769.02	DANNY JOE AND AMANDA BRADFORD	4/12/2012	HOOD			2012-0005640
TX	HOOD	TX2211771.01	SYLVIA NELL CURRY INDIV & TRE	5/1/2012	HOOD			2012-0005479
TX	HOOD	TX2211771.02	CARRIE Y HOWELL INDIV & TRE	5/1/2012	HOOD			2012-0005478
TX	HOOD	TX2211771.03	CARROLL E NIX ET UX IND & TRE	5/1/2012	HOOD			2012-0005480
TX	HOOD	TX2211772.01	RICHARD Y WICKLINE ET UX	4/26/2012	HOOD			2012-0005491
TX	HOOD	TX2211773.00	ROUGH CREEK CEMETERY	5/10/2012	HOOD			2012-0005482
TX	HOOD	TX2211777.01	MARY LOUISE ROLLINS	5/11/2012	HOOD			2012-0005483
TX	HOOD	TX2211777.02	WILLIAM BERRY ROLLINS	5/11/2012	HOOD			2012-0005484
TX	HOOD	TX2211777.03	PATSY TACKETT	4/11/2012	HOOD			2012-0004594
TX	HOOD	TX2211779.00	CLINE FAMILY TRUST A & B	5/1/2012	HOOD			2012-0005638
TX	HOOD	TX2211780.04	BILLY M MANNING JR ET UX	5/29/2012	HOOD			2012-0006753
TX	HOOD	TX2211780.05	CLAYTON MANNING ET UX	9/25/2012	HOOD			2012-0011506
TX	HOOD	TX2211781.99	HILDA M SCHULTZ REVOCABLE TRUST	4/1/2012	HOOD			2012-0006750
TX	HOOD	TX2211782.00	HAROLD GLEN DAVIS	5/21/2012	HOOD			2012-0006392
TX	HOOD	TX2211783.00	FRANK B AND CHARLENE MABERY	6/12/2012	HOOD			2012-0006382
TX	HOOD	TX2211784.00	FRANK B AND CHARLENE MABERY	6/12/2012	HOOD			2012-0006383
TX	HOOD	TX2211785.00	JOHNNY REED	5/21/2012	HOOD			2012-0006387
TX	HOOD	TX2211786.00	JAMES REX DAVIS	5/21/2012	HOOD			2012-0006388
TX	HOOD	TX2211787.01	FRANK B AND CHARLENE MABERY	6/12/2012	HOOD			2012-0006384
TX	HOOD	TX2211787.02	PILGRIM CONGREGATIONAL CHURCH UNITED CHURCH OF CHR	7/5/2012	HOOD			2012-0007861
TX	HOOD	TX2211788.01	THOMAS ALLEN COLEMAN	6/19/2012	HOOD			2012-0006755
TX	HOOD	TX2211788.02	SUE CHERRY COX	6/19/2012	HOOD			2012-0006756
TX	HOOD	TX2211790.00	UNA RUTH DAVIS STERLING	5/21/2012	HOOD			2012-0006757
TX	HOOD	TX2211791.00	RAYMOND DON AND LISA DIANE FORTENBERRY	6/6/2012	HOOD			2012-0006758
TX	HOOD	TX2211792.00	AMMIE AND TAMMIE BAKER	5/30/2012	HOOD			2012-0006954
TX	HOOD	TX2211795.00	DON HUMPHREY ET UX	5/30/2012	HOOD			2012-0006953
TX	HOOD	TX2211796.00	LARRY D NACE ET UX	5/18/2012	HOOD			2012-0006955
TX	HOOD	TX2211798.01	DIANA JUNE AENIS	6/29/2012	HOOD			2012-0007535
TX	HOOD	TX2211798.02	PATRICIA ANN CRAWFORD	6/29/2012	HOOD			2012-0007536
TX	HOOD	TX2211798.03	NADRIA LYNETTE GREEN	6/29/2012	HOOD			2012-0007534
TX	HOOD	TX2211800.01	THOMAS ALLEN COLEMAN	7/3/2012	HOOD			2012-0007532
TX	HOOD	TX2211800.02	SUE CHERRY COX	7/3/2012	HOOD			2012-0007533
TX	HOOD	TX2211802.00	DAVID A & LISA L BROWN	6/14/2012	HOOD			2012-0007529
TX	HOOD	TX2211803.00	LARRY BUCKLES ET UX	7/12/2012	HOOD			2012-0008717
TX	HOOD	TX2211804.01	GARRY NIX	6/25/2012	HOOD			2012-0007864
TX	HOOD	TX2211804.02	LYNN NIX	6/25/2012	HOOD			2012-0007865
TX	HOOD	TX2211804.03	THOMAS D NIX	6/25/2012	HOOD			2012-0007863
TX	HOOD	TX2211804.04	NELDA SUE CUMMINS	6/25/2012	HOOD			2012-0007862
TX	HOOD	TX2211805.01	MARTHA ANN JOHNSON	6/25/2012	HOOD			2012-0008710
TX	HOOD	TX2211806.01	DEBORAH G TOMERLIN	6/7/2012	HOOD			2012-0008705
TX	HOOD	TX2211807.01	GLEN ALAN MUSICK	7/6/2012	HOOD			2012-0008711
TX	HOOD	TX2211807.02	ANNETTE MUSICK	7/6/2012	HOOD			2012-0008712
TX	HOOD	TX2211808.00	JACK & FREEDA IVES REV LIV TR	7/20/2012	HOOD			2012-0008718
TX	HOOD	TX2211809.00	STEPHEN CRAIG HUSTON ET UX	7/23/2012	HOOD			2012-0008713
TX	HOOD	TX2211810.01	HUGO ESCOBAR ET UX	7/20/2012	HOOD			2012-0008714
TX	HOOD	TX2211810.02	RAFAEL AND SUZANNA ORDONEZ	7/24/2012	HOOD			2012-0010125
TX	HOOD	TX2211812.00	JOHN W AND PEGGY N PAPAN	7/25/2012	HOOD			2012-0008719
TX	HOOD	TX2211813.00	BILLY JUDD NEIGHBORS	8/1/2012	HOOD			2012-0008709
TX	HOOD	TX2211815.00	CHRISTINE M MCDONALD	8/3/2012	HOOD			2012-0008707
TX	HOOD	TX2211817.00	JEFFREY L AND ROBERTA R BARLOW	7/19/2012	HOOD			2012-0009054
TX	HOOD	TX2211818.00	MICHAEL A AND JOANN STEPHENS	8/9/2012	HOOD			2012-0009056
TX	HOOD	TX2211819.00	WANDA F MOORE	8/13/2012	HOOD			2012-0009055
TX	HOOD	TX2211820.00	KATHERINE ANN CHURCH	8/22/2012	HOOD			2012-0009592
TX	HOOD	TX2211821.01	JOHN ALLARD ET UX	8/31/2012	HOOD			2012-0010126
TX	HOOD	TX2211822.01	ROY E ROTHE	9/6/2012	HOOD			2012-0010128
TX	HOOD	TX2211823.01	RICHARD L ROTHE ET UX	9/6/2012	HOOD			2012-0010127
TX	HOOD	TX2211825.00	MITTIE LOU WOOLSEY	6/23/2006	HOOD	2220	200	13296
TX	HOOD	TX2211826.00	CARMICHAEL FAMILY TRUST	6/23/2006	HOOD	2201	198	13295
TX	HOOD	TX2211827.00	JAMES L SHAFER ET UX	6/23/2006	HOOD	2220	224	13308
TX	HOOD	TX2211828.00	DAVID AND LYNDEL CAMPBELL	6/23/2006	HOOD	2223	689	14072
TX	HOOD	TX2211829.00	ALLAN RAY CATHEY ET UX	6/23/2006	HOOD	2220	204	13298
TX	HOOD	TX2211830.00	CLIFFORD O HEFLIN JR ET UX	6/23/2006	HOOD	2220	226	13309
TX	HOOD	TX2211831.00	DONALD R ARMSTRONG	7/12/2006	HOOD	2223	701	14078
TX	HOOD	TX2211832.00	JEAN KELLEY SMITH	8/23/2006	HOOD	2236	781	17118
TX	HOOD	TX2211832.00	JEAN KELLEY SMITH	8/23/2006
TX	HOOD	TX2211833.00	TIMOTHY E STEVENS ET UX	11/17/2008	HOOD	2446	897	19655
TX	HOOD	TX2211834.00	ALBERTONI REV TRUST	10/18/2006	HOOD	2281	929	4264
TX	HOOD	TX2211835.00	NICHOLAS K NOE ET UX	11/17/2008	HOOD	2463	466	3206
TX	HOOD	TX2211836.00	JOHN W MINTER II AKA JOHN MINTER	9/15/2012	HOOD			2012-0011507
TX	HOOD	TX2211837.00	JOE D HENDERSON ET UX	7/29/2006	HOOD	2223	691	14073
TX	HOOD	TX2211838.00	JOHNNIE C RAGER ET UX	6/23/2006	HOOD	2220	208	13300
TX	HOOD	TX2211839.00	BEVERLY A CULLUM ET UX	6/23/2006	HOOD	2220	210	13301
TX	HOOD	TX2211840.00	STEPHEN REINKE ET UX	8/30/2011	HOOD			2011-0010183
TX	HOOD	TX2211841.00	JERRY A CAMPBELL	7/14/2006	HOOD	2223	683	14069
TX	HOOD	TX2211848.00	RAY W COX AND JANIE S COX	1/23/2014	HOOD			2014-0002392
TX	HOOD	TX2211849.01	LOFTIN FAMILY TRUST	3/27/2014	HOOD			2014-0003042
TX	HOOD	TX2211849.02	SCOTT LOFTIN	3/27/2014	HOOD			2014-0003041
TX	HOOD	TX2211849.03	MELINDA D'ANN LOFTIN EGGENBERGER	3/27/2014	HOOD			2014-0003530
TX	HOOD	TX2211850.00	HAROLD T JOHNSON SR ET UX	4/4/2014	HOOD			2014-0003531
TX	HOOD	TX2211851.00	MICHAEL W JOHNSON ET UX	4/2/2014	HOOD			2014-0003532
TX	HOOD	TX2211852.00	JEFF BENNETT	4/2/2014	HOOD			2014-0003533
TX	HOOD	TX2211853.01	THOMAS LEE MATLOCK TEST TRUST	4/8/2014	HOOD			2014-0003535
TX	HOOD	TX2211853.02	DEANA ANN GOBLE TEST TRUST	4/8/2014	HOOD			2014-0003534
TX	HOOD	TX2211854.00	JO ANN STEPHENS ET VIR	4/14/2014	HOOD			2014-0003536
TX	HOOD	TX2211855.00	TYRELLA C ROBINSON	4/17/2014	HOOD			2014-0004125
TX	HOOD	TX2211856.00	J WAYNE MILLSAP ET AL	4/23/2014	HOOD			2014-0004126
TX	HOOD	TX2211857.01	MARJORIE LEITO	4/30/2014	HOOD			2014-0004526
TX	HOOD	TX2211858.00	RONALD L MABERY ET UX	5/15/2014	HOOD			2014-0005335
TX	HOOD	TX2211859.00	WARREN W MARSHALL, ET UX	4/8/2014	HOOD			2014-0005332
TX	HOOD	TX2211860.01	MARY ELIZABETH BROWN	5/20/2014	HOOD			2014-0005333
TX	HOOD	TX2211860.02	PEGGY JOYCE COLE	6/10/2014	HOOD			2014-0006973
TX	HOOD	TX2211861.00	A L WARDEN	5/16/2014	HOOD			2014-0005334
TX	HOOD	TX2211862.00	THOMAS W TANKERSLEY ET UX	5/20/2014	HOOD			2014-0006016
TX	HOOD	TX2211863.00	WILLIAM E PARMER ET UX	6/6/2014	HOOD			2014-0006014
TX	HOOD	TX2211864.00	SANDRA L RIDDLE	6/12/2014	HOOD			2014-0006015
TX	HOOD	TX2211865.00	MICHAEL CALDWELL ET UX	5/12/2014	HOOD			2014-0006387
TX	HOOD	TX2211866.01	BASCOM M HIGGINBOTTOM ET UX	6/18/2014	HOOD			2014-0006012
TX	HOOD	TX2211867.00	WILLIAM M DANIELS ET UX	6/10/2014	HOOD			2014-0006386
TX	HOOD	TX2211868.00	BRUCE ARMSTRONG ET UX	6/18/2014	HOOD			2014-0006385
TX	HOOD	TX2211869.01	SUE CHERRY COX ET VIR	6/19/2014	HOOD			2014-0006977
TX	HOOD	TX2211869.02	THOMAS ALLEN COLEMAN	6/19/2014	HOOD			2014-0006975
TX	HOOD	TX2211870.00	JAMES C BARRON	6/19/2014	HOOD			2014-0006976
TX	HOOD	TX2211871.00	ROGER B IVES ET UX	6/6/2014	HOOD			2014-0006974
TX	HOOD	TX2211873.00	JEWEL ELIZABETH MARLOW	6/18/2014	HOOD			2014-0006980
TX	HOOD	TX2211874.01	VIRGINIA NUTT JONES	7/10/2014	HOOD			2014-0007538
TX	HOOD	TX2211874.02	MILBURN E NUTT JR	7/10/2014	HOOD			2014-0007539
TX	HOOD	TX2211874.03	SUN CHASE DEVELOPMENT CO	7/15/2014	HOOD			2014-0007533
TX	HOOD	TX2211874.04	GARRY Z LUKER DBA GRANBURY LAN	7/15/2014	HOOD			2014-0007534
TX	HOOD	TX2211875.00	REGINALD T BUTLER, ET UX	6/24/2014	HOOD			2014-0007540
TX	HOOD	TX2211876.00	GERALD WILLIAM BUTLER ESTATE	6/24/2014	HOOD			2014-0007541
TX	HOOD	TX2211877.00	DARWIN L DAVIS ET UX	7/16/2014	HOOD			2014-0007542
TX	HOOD	TX2211878.00	JEANETTA A GREEN	7/14/2014	HOOD			2014-0007543
TX	HOOD	TX2211879.00	AARON B GREEN ET UX	7/7/2014	HOOD			2014-0007544
TX	HOOD	TX2211880.00	DAVID L BRISTER EX UX	6/26/2014	HOOD			2014-0007536
TX	HOOD	TX2211881.00	PAUL B IVES EX UX	7/21/2014	HOOD			2014-0007535
TX	HOOD	TX2211882.01	GLYNN W WOOD	6/25/2014	HOOD			2014-0007537
TX	HOOD	TX2211882.02	CHARLES D LOVING ET UX	1/29/2015	HOOD			2015-0003652
TX	HOOD	TX2211883.00	RODNEY B SHAW ET UX	7/7/2014	HOOD			2014-0008773
TX	HOOD	TX2211884.00	BILLY DUMAS ET UX	7/21/2014	HOOD			2014-0008781
TX	HOOD	TX2211885.00	CAROL RASBERRY	7/21/2014	HOOD			2014-0008779
TX	HOOD	TX2211886.00	WADE PRESTON DOLLARHIDE ET UX	7/21/2014	HOOD			2014-0008783
TX	HOOD	TX2211887.00	WAPLES COMMUNITY CENTER	7/31/2014	HOOD			2014-0008776
TX	HOOD	TX2211888.01	DANNY M WOOD	6/30/2014	HOOD			2014-0008782
TX	HOOD	TX2211889.01	DONNY B HAYWORTH, ET UX	7/10/2014	HOOD			2014-0008778
TX	HOOD	TX2211889.02	ESTATE OF D J KINSON	9/4/2014	HOOD			2014-0011184
TX	HOOD	TX2211890.01	JAMES BRYAN NOBLITT ET UX	6/24/2014	HOOD			2014-0008775
TX	HOOD	TX2211890.02	ROBERT MILTON NOBLITT ET UX	6/24/2014	HOOD			2014-0008774
TX	HOOD	TX2211891.01	DONALD MARTON SAVAGE ET UX	6/30/2014	HOOD			2014-0008780
TX	HOOD	TX2211891.02	JANICE MARIE SAVAGE	8/5/2014	HOOD			2014-0008770
TX	HOOD	TX2211892.00	DAVID T LOCK ET UX	7/1/2014	HOOD			2014-0008761
TX	HOOD	TX2211893.01	WAB & JBB FAMILY LP NO 1	8/4/2014	HOOD			2014-0008760
TX	HOOD	TX2211893.02	VIRGINIA A REED	8/7/2014	HOOD			2014-0008759
TX	HOOD	TX2211894.01	FAYE BETHEL HOBBS	7/7/2014	HOOD			2014-0008762
TX	HOOD	TX2211894.02	LUDWICK REVOCABLE LIVING TRUST	7/7/2014	HOOD			2014-0008765
TX	HOOD	TX2211894.03	SHIRLEY LEE LUDWICK	7/7/2014	HOOD			2014-0008764
TX	HOOD	TX2211895.01	HOBBS REVOCABLE LIVING TRUST	7/7/2014	HOOD			2014-0008763
TX	HOOD	TX2211896.00	JACK L SCOTT ET UX	7/9/2014	HOOD			2014-0008766
TX	HOOD	TX2211897.01	BRENDA STEWART ET UX	8/5/2014	HOOD			2014-0008769
TX	HOOD	TX2211897.02	BETTY Z JOHNSTON	8/6/2014	HOOD			2014-0009289
TX	HOOD	TX2211897.03	CYNTHIA MORRIS	8/7/2014	HOOD			2014-0009287
TX	HOOD	TX2211897.04	STEPHAN KRONBERGER	8/1/2014	HOOD			2014-0009288
TX	HOOD	TX2211897.05	LONNIE MACK JORDAN	9/15/2014	HOOD			2014-0010050
TX	HOOD	TX2211897.06	PAMELA JORDAN SPENCE	8/25/2014	HOOD			2014-0010051
TX	HOOD	TX2211897.07	RANDAL JORDAN	9/20/2014	HOOD			2014-0010039
TX	HOOD	TX2211897.08	MAX L BRADSHAW JR ET UX	8/11/2014	HOOD			2014-0010592
TX	HOOD	TX2211897.09	ROGER JORDAN ET UX	9/15/2014	HOOD			2014-0010591
TX	HOOD	TX2211897.10	AUSTIN RAY	10/1/2014	HOOD			2014-0010601
TX	HOOD	TX2211897.11	PATTY ROOKS	10/18/2014	HOOD			2014-0011172
TX	HOOD	TX2211897.12	ROBERT H DUFFIE	10/14/2014	HOOD			2014-0011171
TX	HOOD	TX2211897.13	ANNA JEAN MATHIS	9/30/2014	HOOD			2014-0011179
TX	HOOD	TX2211897.14	AARON RAY	10/1/2014	HOOD			2014-0011185
TX	HOOD	TX2211897.15	ASHLEIGH BELL	10/1/2014	HOOD			2014-0011186
TX	HOOD	TX2211897.16	JAMIE OLSON ET VIR	10/6/2014	HOOD			2014-0012081
TX	HOOD	TX2211897.17	PAULA JORDAN CHRISTOPHER	10/29/2014	HOOD			2015-0000665
TX	HOOD	TX2211897.18	JACKIE FRANK RAINES	11/17/2014	HOOD			2015-0002340
TX	HOOD	TX2211898.00	DEWAIN WEBB ET UX	7/25/2014	HOOD			2014-0008771
TX	HOOD	TX2211899.01	DENISE MICHELLE LIZUN	7/22/2014	HOOD			2014-0008772
TX	HOOD	TX2211899.02	JOYCE SANDERS	7/22/2014	HOOD			2014-0009294
TX	HOOD	TX2211900.00	JOHN W FISK & ELSA DAVALOS JT	8/20/2014	HOOD			2014-0009295
TX	HOOD	TX2211901.00	BILLY R SNELLGROVE ET UX	7/25/2014	HOOD			2014-0009293
TX	HOOD	TX2211902.00	DAVID WEBB ET UX	7/25/2014	HOOD			2014-0009292
TX	HOOD	TX2211903.00	TOBE L JOHNSTON ET UX	8/21/2014	HOOD			2014-0009290
TX	HOOD	TX2211904.01	JIMMY MORRIS ET UX	8/29/2014	HOOD			2014-0009286
TX	HOOD	TX2211904.02	SCOTT BEYER ET UX	10/16/2014	HOOD			2014-0012092
TX	HOOD	TX2211905.01	DICKSON 2008 MANAGEMENT TRUST	7/28/2014	HOOD			2014-0009291
TX	HOOD	TX2211906.01	BRUCE GIBBS ET UX	8/8/2014	HOOD			2014-0009285
TX	HOOD	TX2211907.01	LARRY GILDER	8/8/2014	HOOD			2014-0009284
TX	HOOD	TX2211908.01	MARCY GILBREATH	8/11/2014	HOOD			2014-0009283
TX	HOOD	TX2211908.02	BARRY K GILBREATH	8/11/2014	HOOD			2014-0009282
TX	HOOD	TX2211909.01	HENRY K SMITH	8/11/2014	HOOD			2014-0009281
TX	HOOD	TX2211909.02	JODY L SPARKS ET UX	8/11/2014	HOOD			2014-0010593
TX	HOOD	TX2211910.01	WILSON FAMILY TRUST	7/30/2014	HOOD			2014-0010046
TX	HOOD	TX2211911.01	CHEYNE FAMILY TRUST	8/12/2014	HOOD			2014-0010047
TX	HOOD	TX2211912.01	DONNA J FULTZ	8/27/2014	HOOD			2014-0010043
TX	HOOD	TX2211912.02	VICKIE L ATKINS	8/27/2014	HOOD			2014-0010044
TX	HOOD	TX2211913.01	BETTY HENSON IND & AS TRUSTEE	9/3/2014	HOOD			2014-0010045
TX	HOOD	TX2211913.02	THOMAS NEAL RICHARDS	9/5/2014	HOOD			2014-0010041
TX	HOOD	TX2211913.03	MARY KATHRYN CARR	9/5/2014	HOOD			2014-0010042
TX	HOOD	TX2211914.01	WINFRED HOOPER JR	8/19/2014	HOOD			2014-0010040
TX	HOOD	TX2211914.02	DESERT PARTNERS III LP	11/4/2014	HOOD			2015-0000663
TX	HOOD	TX2211914.03	J KYLE JONES	12/16/2014	HOOD			2015-0002328
TX	HOOD	TX2211914.04	GEORGE MORETTI JR	12/16/2014	HOOD			2015-0002324
TX	HOOD	TX2211915.00	ALFREDO TRIANA ET UX	9/9/2014	HOOD			2014-0010589
TX	HOOD	TX2211916.00	RODNEY CARROL COX	9/9/2014	HOOD			2014-0010587
TX	HOOD	TX2211917.00	MONTY L JACOB ET UX	8/19/2014	HOOD			2014-0010586
TX	HOOD	TX2211918.00	HERBERT L WAGNER ET UX	9/17/2014	HOOD			2014-0010588
TX	HOOD	TX2211919.00	JOHNATHAN WESLEY SMITH ET UX	9/8/2014	HOOD			2014-0010590
TX	HOOD	TX2211920.00	BILLY W DUNBAR ET UX	9/3/2014	HOOD			2014-0010594
TX	HOOD	TX2211921.01	VICTOR ALLEN HALFON ET UX	8/20/2014	HOOD			2014-0010597
TX	HOOD	TX2211921.02	ROYCE MCINTIRE ET UX	8/20/2014	HOOD			2014-0010598
TX	HOOD	TX2211922.00	BROOKLYN NICOLE KERR	9/4/2014	HOOD			2014-0010595
TX	HOOD	TX2211923.00	FRANK KIMMELL ET UX	8/26/2014	HOOD			2014-0010596
TX	HOOD	TX2211924.00	WILLIAM L KENLEY	10/6/2014	HOOD			2014-0010599
TX	HOOD	TX2211925.00	TONY ODELL MEEKER ET UX	9/10/2014	HOOD			2014-0010600
TX	HOOD	TX2211926.01	JAMES H GILLIAM	8/28/2014	HOOD			2014-0011177
TX	HOOD	TX2211926.02	VERA NANNY	9/8/2014	HOOD			2014-0011176
TX	HOOD	TX2211926.03	LINDA KILLOUGH	9/8/2014	HOOD			2014-0011175
TX	HOOD	TX2211926.04	BILL G RUSSELL JR ET UX	10/16/2014	HOOD			2014-0011170
TX	HOOD	TX2211926.05	GINGER ZOE SMITH / VLB	11/20/2014	HOOD			2015-0002341
TX	HOOD	TX2211926.06	GINGER ZOE SMITH	11/20/2014	HOOD			2015-0002339
TX	HOOD	TX2211926.07	CARLA BECK CURTIS	11/3/2014	HOOD			2015-0000674
TX	HOOD	TX2211927.00	JOEY G WHITE ET UX	10/7/2014	HOOD			2014-0011180
TX	HOOD	TX2211928.00	VICKI VALENA JACOB	9/9/2014	HOOD			2014-0011167
TX	HOOD	TX2211929.00	JUAN A ARANDA ET UX	8/28/2014	HOOD			2014-0011182
TX	HOOD	TX2211930.01	DANIEL H LEDFORD ET UX	9/3/2014	HOOD			2014-0011183
TX	HOOD	TX2211930.02	JAMES L SMITH ET UX	8/29/2014	HOOD			2014-0011181
TX	HOOD	TX2211933.01	DIXIE ALENE PARKER	10/13/2014	HOOD			2014-0011165
TX	HOOD	TX2211933.02	CHARLES W BRIDIER ET UX	10/13/2014	HOOD			2014-0012082
TX	HOOD	TX2211933.03	BILLY C SIMMS ET UX	10/15/2014	HOOD			2014-0012087
TX	HOOD	TX2211933.04	LAURA J DICKERSON ET VIR	10/15/2014	HOOD			2014-0012088
TX	HOOD	TX2211933.05	HANDLEY CHURCH OF CHRIST	10/21/2014	HOOD			2015-0000662
TX	HOOD	TX2211933.06	CINDY L BAUGHMAN	11/25/2014	HOOD			2015-0000660
TX	HOOD	TX2211934.00	JAMES DALE EVERETTE ET UX	10/3/2014	HOOD			2014-0012083
TX	HOOD	TX2211935.01	EDWIN H MCMAHON JR	8/27/2014	HOOD			2014-0012085
TX	HOOD	TX2211935.02	EDWIN G HARMON ET UX	9/15/2014	HOOD			2014-0012084
TX	HOOD	TX2211935.03	CLAUDE TIMOTHY MARSHALL	9/15/2014	HOOD			2014-0012086
TX	HOOD	TX2211936.00	RONALD G ATKINSON ET UX	10/9/2014	HOOD			2014-0012080
TX	HOOD	TX2211937.00	FRED EARL SNOWDON ET UX	10/7/2014	HOOD			2014-0012079
TX	HOOD	TX2211938.01	HERMAN L BURNETT ET UX	10/3/2014	HOOD			2014-0012078
TX	HOOD	TX2211940.00	LAWRENCE J RYAN ET UX	10/27/2014	HOOD			2014-0012093
TX	HOOD	TX2211941.01	RICK DON CARVER ET UX	10/19/2014	HOOD			2014-0012094
TX	HOOD	TX2211942.00	WAYNE WIENECKE	11/12/2014	HOOD			2014-0012089
TX	HOOD	TX2211943.01	JULIAN O READ	9/25/2014	HOOD			2014-0011166
TX	HOOD	TX2211944.01	ROBERT J CHISOLM ET UX	11/21/2014	HOOD			2015-0000678
TX	HOOD	TX2211945.00	JOHN RUSSELL PECKHAM ET UX	11/21/2014	HOOD			2015-0000680
TX	HOOD	TX2211946.00	JOHN RUSSELL PECKHAM ET UX	11/21/2014	HOOD			2015-0000682
TX	HOOD	TX2211947.00	JOHN RUSSELL PECKHAM ET UX	11/21/2014	HOOD			2015-0000681
TX	HOOD	TX2211948.00	ROBERT J CHISOLM ET UX	11/21/2014	HOOD			2015-0000679
TX	HOOD	TX2211949.00	MARK DEMPSEY ET UX	12/2/2014	HOOD			2015-0000664
TX	HOOD	TX2211950.01	GARY SHAW ET UX	11/13/2014	HOOD			2015-0000661
TX	HOOD	TX2211950.02	SHERON L VARIN	12/17/2014	HOOD			2015-0000675
TX	HOOD	TX2211950.03	KEITH C HAMBY	12/16/2014	HOOD			2015-0000676
TX	HOOD	TX2211950.04	JUDY L GRANT	12/9/2014	HOOD			2015-0000683
TX	HOOD	TX2211950.05	GREGORY T HAMBY	2/12/2015	HOOD			2015-0004374
TX	HOOD	TX2211951.00	WILLARD R SCHUESSLER ET UX	10/8/2014	HOOD			2015-0000666
TX	HOOD	TX2211952.00	ROBERT MOORE ET UX	12/2/2014	HOOD			2015-0000673
TX	HOOD	TX2211953.00	TOMMY R MATTHEWS ET UX	10/21/2014	HOOD			2015-0000672
TX	HOOD	TX2211954.00	SARAH BOGGS ET VIR	12/9/2014	HOOD			2015-0000671
TX	HOOD	TX2211955.00	JEFF D WALKER ET UX	11/21/2014	HOOD			2015-0000677
TX	HOOD	TX2211956.00	CDI TRANSPORTATION LEASING INC	12/8/2014	HOOD			2015-0000657
TX	HOOD	TX2211957.01	WESLEY IVES ET UX	11/21/2014	HOOD			2015-0002325
TX	HOOD	TX2211958.00	KATHLEEN GENTRY RUNNING	1/6/2015	HOOD			2015-0002342
TX	HOOD	TX2211961.01	WILLIAM ROSS MARTIN ET UX	10/27/2004	HOOD	2055	181	18428
TX	HOOD AND JOHNSON	TX2510003.01	HARRELL GEORGE ET UX	2/23/2001	HOOD	2601	983	6482
TX	HOOD AND JOHNSON	TX2510003.01	HARRELL GEORGE ET UX	2/23/2001
TX	HOOD AND JOHNSON	TX2510003.02	FARR JACK ET UX	3/25/2004	HOOD	2000	810	6150
TX	HOOD AND JOHNSON	TX2510003.02	FARR JACK ET UX	3/25/2004
TX	HOOD AND JOHNSON	TX2510003.02	FARR JACK ET UX	3/25/2004
TX	HOOD AND JOHNSON	TX2510003.02	FARR JACK ET UX	3/25/2004
TX	HOOD, JOHNSON AND PARKER	TX2510022.00	JOHN J MILES ET AL	4/20/1996	JOHNSON	2039	983	2949
TX	HOOD, JOHNSON AND PARKER	TX2510022.00	JOHN J MILES ET AL	4/20/1996
TX	HOOD, JOHNSON AND PARKER	TX2510022.00	JOHN J MILES ET AL	4/20/1996	HOOD	1541	135	5708
TX	HOOD, JOHNSON AND PARKER	TX2510022.00	JOHN J MILES ET AL	4/20/1996
TX	HOOD, JOHNSON AND PARKER	TX2510022.00	JOHN J MILES ET AL	4/20/1996	PARKER	1717	1302	314433
TX	HOOD, JOHNSON AND PARKER	TX2510022.00	JOHN J MILES ET AL	4/20/1996
TX	HOOD, JOHNSON AND SOMERVELL	TX2510025.01	VIRGINIA L RINGLER IND/TRE	9/23/2003	JOHNSON	3160	282	36566
TX	HOOD, JOHNSON AND SOMERVELL	TX2510025.01	VIRGINIA L RINGLER IND/TRE	9/23/2003	SOMERVELL	117	843	35841
TX	HOOD, JOHNSON AND SOMERVELL	TX2510025.01	VIRGINIA L RINGLER IND/TRE	9/23/2003
TX	JOHNSON AND HOOD	TX2510045.00	JACK C SCOTT	1/23/1997	JOHNSON	2077	542	12822
TX	JOHNSON AND HOOD	TX2510045.00	JACK C SCOTT	1/23/1997
TX	JOHNSON AND HOOD	TX2510047.00	DAVID LEWIS ROSS	3/20/1997	JOHNSON	2077	545	12823
TX	JOHNSON AND HOOD	TX2510047.00	DAVID LEWIS ROSS	3/20/1997
TX	HOOD AND JOHNSON	TX2510052.00	ST TX M-104002	7/6/2004	HOOD	2042	743	15464
TX	HOOD AND JOHNSON	TX2510052.00	ST TX M-104002	7/6/2004	JOHNSON	3391	432	33509
TX	HOOD AND SOMERVELL	TX4250026.00	PERRY J ADAMS ET UX	6/23/2003	SOMERVELL	112	765	34896
TX	HOOD AND SOMERVELL	TX4250026.00	PERRY J ADAMS ET UX	6/23/2003	HOOD	1927	200	10494
TX	HOOD AND SOMERVELL	TX4250026.00	PERRY J ADAMS ET UX	6/23/2003
TX	HOOD AND SOMERVELL	TX4250039.00	ALYCIA R PROCTER LIVING TR	7/9/2003	HOOD	1937	594	12649
TX	HOOD AND SOMERVELL	TX4250039.00	ALYCIA R PROCTER LIVING TR	7/9/2003	SOMERVELL	115	40	35273
TX	HOOD AND SOMERVELL	TX4250065.00	ROBERT KING ET UX	8/25/2003	SOMERVELL	117	23	35666
TX	HOOD AND SOMERVELL	TX4250065.00	ROBERT KING ET UX	8/25/2003	HOOD	1951	585	15657
TX	HOOD AND SOMERVELL	TX4250099.00	ST TX M-103313	10/7/2003	SOMERVELL	119	823	36231
TX	HOOD AND SOMERVELL	TX4250099.00	ST TX M-103313	10/7/2003	HOOD	1969	424	19798
TX	HOOD AND SOMERVELL	TX4250228.41	UNIMIN TEXAS COMPANY L P	6/25/2004	HOOD	2021	995	10552
TX	HOOD AND SOMERVELL	TX4250228.41	UNIMIN TEXAS COMPANY L P	6/25/2004
TX	HOOD AND SOMERVELL	TX4250228.41	UNIMIN TEXAS COMPANY L P	6/25/2004
TX	HOOD AND SOMERVELL	TX4250228.41	UNIMIN TEXAS COMPANY L P	6/25/2004
TX	HOOD AND SOMERVELL	TX4250228.41	UNIMIN TEXAS COMPANY L P	6/25/2004	SOMERVELL	128	590	37891
TX	HOOD AND SOMERVELL	TX4250228.41	UNIMIN TEXAS COMPANY L P	6/25/2004
TX	HOOD AND SOMERVELL	TX4250228.41	UNIMIN TEXAS COMPANY L P	6/25/2004
TX	HOOD AND SOMERVELL	TX4250228.41	UNIMIN TEXAS COMPANY L P	6/25/2004
TX	HOOD AND SOMERVELL	TX4250228.41	UNIMIN TEXAS COMPANY L P	6/25/2004
TX	HOOD AND SOMERVELL	TX4250892.00	ST TX M-108269	9/18/2007
TX	HOOD AND SOMERVELL	TX4251096.99	D SKJEVELAND / QRI	8/1/2013	HOOD			2013-0009581
TX	HOOD AND SOMERVELL	TX4251096.99	D SKJEVELAND / QRI	8/1/2013	SOMERVELL			20131299
TX	HOOD AND JOHNSON	TX2210006.01	MICHAEL MOONEY ET UX	4/2/2003	HOOD	1909	69	17436
TX	HOOD AND JOHNSON	TX2210006.01	MICHAEL MOONEY ET UX	4/2/2003	JOHNSON	3050	480	6760
TX	HOOD AND JOHNSON	TX2210006.04	HEATHER BELZ	8/22/2007	JOHNSON	4212	273	45291
TX	HOOD AND JOHNSON	TX2210006.04	HEATHER BELZ	8/22/2007
TX	HOOD AND JOHNSON	TX2210006.04	HEATHER BELZ	8/22/2007	JOHNSON	4212	273	45291
TX	HOOD AND JOHNSON	TX2210006.04	HEATHER BELZ	8/22/2007
TX	HOOD AND JOHNSON	TX2210006.05	JENNIFER BELZ	8/22/2007	JOHNSON	4212	269	45290
TX	HOOD AND JOHNSON	TX2210006.05	JENNIFER BELZ	8/22/2007
TX	JOHNSON	TX2210006.06	MARGARET S DEAR ET VIR	12/22/2007	JOHNSON	4267	263	722
TX	HOOD AND JOHNSON	TX2210006.06	TIM J CECIL	12/22/2007	JOHNSON	4267	263	722
TX	HOOD AND JOHNSON	TX2210006.06	MARGARET S DEAR ET VIR	12/22/2007
TX	HOOD, JOHNSON AND SOMERVELL	TX2210006.07	WALTER E PARKER ET AL	2/20/2003	HOOD	1917	324	8589
TX	HOOD, JOHNSON AND SOMERVELL	TX2210006.07	WALTER E PARKER ET AL	2/20/2003	JOHNSON	3040	609	34443
TX	HOOD, JOHNSON AND SOMERVELL	TX2210006.07	WALTER E PARKER ET AL	2/20/2003	SOMERVELL	110	183	15685
TX	HOOD, JOHNSON AND SOMERVELL	TX2210006.08	CAULTHROPE S HINTON ET UX	6/10/2003	HOOD	1939	515	13043
TX	HOOD, JOHNSON AND SOMERVELL	TX2210006.08	CAULTHROPE S HINTON ET UX	6/10/2003	JOHNSON	3114	593	28538
TX	HOOD, JOHNSON AND SOMERVELL	TX2210006.08	CAULTHROPE S HINTON ET UX	6/10/2003	SOMERVELL	115	251	35324
TX	HOOD AND JOHNSON	TX2210016.01	JOE LANGDON ET UX	4/16/2003	HOOD	1917	348	8596
TX	HOOD AND JOHNSON	TX2210016.01	JOE LANGDON ET UX	4/16/2003	JOHNSON	3454	536	1766
TX	HOOD AND JOHNSON	TX2210016.05	JACK LANGDON TRUST ET AL	6/12/2003	HOOD	1937	601	12652
TX	HOOD AND JOHNSON	TX2210016.05	JACK LANGDON TRUST ET AL	6/12/2003	JOHNSON	3454	547	1767
TX	HOOD AND JOHNSON	TX2210016.06	LANGDON JR JAMES C ET UX	12/10/2003	HOOD	1987	582	3011
TX	HOOD AND JOHNSON	TX2210016.06	LANGDON JR JAMES C ET UX	12/10/2003	JOHNSON	3665	848	40285
TX	HOOD AND JOHNSON	TX2210117.00	ST TX M-103311	10/7/2003	HOOD	1966	259	19061
TX	HOOD AND JOHNSON	TX2210117.00	ST TX M-103311	10/7/2003	JOHNSON	3221	268	3294
TX	HOOD AND JOHNSON	TX2210152.01	PALLMEYER WYNONIA IND/TRE	2/23/2004	HOOD	1987	596	3016
TX	HOOD AND JOHNSON	TX2210152.01	PALLMEYER WYNONIA IND/TRE	2/23/2004
TX	HOOD AND JOHNSON	TX2210152.01	PALLMEYER WYNONIA IND/TRE	2/23/2004
TX	HOOD AND JOHNSON	TX2210152.01	PALLMEYER WYNONIA IND/TRE	2/23/2004
TX	HOOD AND JOHNSON	TX2210152.02	ROBERT RASH COPE	3/4/2005	HOOD	2087	243	4504
TX	HOOD AND JOHNSON	TX2210152.02	ROBERT RASH COPE	3/4/2005	JOHNSON	3506	354	11432
TX	HOOD AND JOHNSON	TX2210152.03	MICHAEL WINBURY SPILLER	3/10/2005	HOOD	2087	246	4505
TX	HOOD AND JOHNSON	TX2210152.03	MICHAEL WINBURY SPILLER	3/10/2005	JOHNSON	3506	358	11433
TX	HOOD AND JOHNSON	TX2211235.00	ST TX M 108832 / M MOONEY ET UX	2/26/2008	HOOD	2384	675	4708
TX	HOOD AND JOHNSON	TX2211235.00	ST TX M 108832 / M MOONEY ET UX	2/26/2008	JOHNSON	4319	694	10976
TX	JOHNSON	TX2510001.01	THOMPSON FAYNE H	2/21/2001	JOHNSON	2604	414	7008
TX	JOHNSON	TX2510001.02	HINES PAUL W	2/21/2001	JOHNSON	2617	672	9585
TX	JOHNSON	TX2510001.03	KINDER ROYAL C	2/21/2001	JOHNSON	2604	402	7006
TX	JOHNSON	TX2510002.01	THOMPSON FAYNE H	2/21/2001	JOHNSON	2604	408	7007
TX	JOHNSON	TX2510002.02	HINES PAUL W	2/21/2001	JOHNSON	2617	684	9587
TX	JOHNSON	TX2510002.03	KINDER ROYAL C	2/21/2001	JOHNSON	2604	396	7005
TX	HOOD AND JOHNSON	TX2510003.01	HARRELL GEORGE ET UX	2/23/2001	HOOD	2601	983	6482
TX	HOOD AND JOHNSON	TX2510003.01	HARRELL GEORGE ET UX	2/23/2001
TX	HOOD AND JOHNSON	TX2510003.02	FARR JACK ET UX	3/25/2004	HOOD	2000	810	6150
TX	HOOD AND JOHNSON	TX2510003.02	FARR JACK ET UX	3/25/2004
TX	HOOD AND JOHNSON	TX2510003.02	FARR JACK ET UX	3/25/2004
TX	HOOD AND JOHNSON	TX2510003.02	FARR JACK ET UX	3/25/2004
TX	JOHNSON	TX2510004.00	HOGAN TOMMY L ET UX	3/12/2001	JOHNSON	2617	678	9586
TX	JOHNSON	TX2510006.01	FLOYD E ORMSBY JR IND & TR	4/16/2001	JOHNSON	2694	590	24271
TX	JOHNSON	TX2510006.02	ABILENE CHRISTIAN UNIV	10/20/2003	JOHNSON	3164	13	37287
TX	JOHNSON	TX2510017.01	FREELAND CYNTHIA ANN	8/6/2003	JOHNSON	3118	558	29237
TX	JOHNSON	TX2510017.02	MCWHORTER MYRTLE FREELAND	8/6/2003	JOHNSON	3118	553	29236
TX	JOHNSON	TX2510018.00	R K HANGER TRUST	9/1/2003	JOHNSON	3128	688	30870
TX	JOHNSON	TX2510020.00	CHARCA LIMITED	8/19/2003	JOHNSON	3117	677	29069
TX	HOOD, JOHNSON AND PARKER	TX2510022.00	JOHN J MILES ET AL	4/20/1996	JOHNSON	2039	983	2949
TX	HOOD, JOHNSON AND PARKER	TX2510022.00	JOHN J MILES ET AL	4/20/1996
TX	HOOD, JOHNSON AND PARKER	TX2510022.00	JOHN J MILES ET AL	4/20/1996	HOOD	1541	135	5708
TX	HOOD, JOHNSON AND PARKER	TX2510022.00	JOHN J MILES ET AL	4/20/1996
TX	HOOD, JOHNSON AND PARKER	TX2510022.00	JOHN J MILES ET AL	4/20/1996	PARKER	1717	1302	314433
TX	HOOD, JOHNSON AND PARKER	TX2510022.00	JOHN J MILES ET AL	4/20/1996
TX	HOOD, JOHNSON AND SOMERVELL	TX2510025.01	VIRGINIA L RINGLER IND/TRE	9/23/2003	JOHNSON	3160	282	36566
TX	HOOD, JOHNSON AND SOMERVELL	TX2510025.01	VIRGINIA L RINGLER IND/TRE	9/23/2003	SOMERVELL	117	843	35841
TX	HOOD, JOHNSON AND SOMERVELL	TX2510025.01	VIRGINIA L RINGLER IND/TRE	9/23/2003
TX	JOHNSON AND SOMERVELL	TX2510025.02	O'GRADY SIX O RANCH	1/14/2004	JOHNSON	3213	949	1907
TX	JOHNSON AND SOMERVELL	TX2510025.02	O'GRADY SIX O RANCH	1/14/2004	SOMERVELL	121	839	36600
TX	JOHNSON	TX2510034.00	MARK A IRVIN ET UX	11/12/2003	JOHNSON	3213	967	1912
TX	JOHNSON	TX2510034.00	MARK A IRVIN ET UX	11/12/2003		3939	540	45833
TX	JOHNSON	TX2510035.01	MONTY WADE IRVIN ET UX	11/12/2003	JOHNSON	3213	971	1913
TX	JOHNSON	TX2510035.01	MONTY WADE IRVIN ET UX	11/12/2003	JOHNSON	3939	538	45832
TX	JOHNSON	TX2510036.01	GEORGE IRVIN ET UX	11/12/2003	JOHNSON	3213	963	1911
TX	JOHNSON	TX2510036.01	GEORGE IRVIN ET UX	11/12/2003	JOHNSON	3939	534	45830
TX	JOHNSON	TX2510043.00	JOHN MATTHEW MILES ET UX	1/23/1997	JOHNSON	2070	31	11053
TX	JOHNSON	TX2510044.01	CHARLES MICHAEL COX ET UX	5/17/1996	JOHNSON	2072	567
TX	JOHNSON AND HOOD	TX2510045.00	JACK C SCOTT	1/23/1997	JOHNSON	2077	542	12822
TX	JOHNSON AND HOOD	TX2510045.00	JACK C SCOTT	1/23/1997
TX	JOHNSON	TX2510046.00	LARRY W TYLER ET UX	7/1/1996	JOHNSON	2072	416	11592
TX	JOHNSON AND HOOD	TX2510047.00	DAVID LEWIS ROSS	3/20/1997	JOHNSON	2077	545	12823
TX	JOHNSON AND HOOD	TX2510047.00	DAVID LEWIS ROSS	3/20/1997
TX	JOHNSON	TX2510048.00	ST TX M-98484	8/5/1997	JOHNSON	3237	81	6225
TX	HOOD AND JOHNSON	TX2510052.00	ST TX M-104002	7/6/2004	HOOD	2042	743	15464
TX	HOOD AND JOHNSON	TX2510052.00	ST TX M-104002	7/6/2004	JOHNSON	3391	432	33509
TX	JOHNSON	TX2510055.00	BEN W SMELLEY ET AL/CO-EXE	5/8/2001	JOHNSON	2662	224	17924
TX	JOHNSON	TX2510056.WD	J D ROSE	11/10/2004	JOHNSON	3423	858	39544
TX	JOHNSON	TX2510057.01	JENNIFER DE BURNS ET AL	12/16/2004	JOHNSON	3448	433	682
TX	JOHNSON	TX2510057.02	FLOYD E ORMSBY JR IND & TR	4/16/2001	JOHNSON	2694	584	24270
TX	JOHNSON	TX2510062.99	DEWAYNE BURNS	5/22/2007	JOHNSON	4100	125	22625
TX	JOHNSON	TX2510069.00	ST TX M-110180	5/19/2009	JOHNSON
TX	JOHNSON AND SOMERVELL	TX4250001.01	S GREGORY FAMILY LIMITED	3/6/2003	JOHNSON	3047	270	16842
TX	JOHNSON AND SOMERVELL	TX4250001.01	S GREGORY FAMILY LIMITED	3/6/2003	SOMERVELL	110	178	34442
TX	JOHNSON AND SOMERVELL	TX4250001.01	S GREGORY FAMILY LIMITED	3/6/2003
TX	JOHNSON AND SOMERVELL	TX4250008.00	REECE WHITE ET UX	3/8/2001	JOHNSON	3003	356	9112
TX	JOHNSON AND SOMERVELL	TX4250008.00	REECE WHITE ET UX	3/8/2001	SOMERVELL	88	127	30118
TX	HOOD, JOHNSON AND PARKER	TX2510022.00	JOHN J MILES ET AL	4/20/1996	JOHNSON	2039	983	2949
TX	HOOD, JOHNSON AND PARKER	TX2510022.00	JOHN J MILES ET AL	4/20/1996
TX	HOOD, JOHNSON AND PARKER	TX2510022.00	JOHN J MILES ET AL	4/20/1996	HOOD	1541	135	5708
TX	HOOD, JOHNSON AND PARKER	TX2510022.00	JOHN J MILES ET AL	4/20/1996
TX	HOOD, JOHNSON AND PARKER	TX2510022.00	JOHN J MILES ET AL	4/20/1996	PARKER	1717	1302	314433
TX	HOOD, JOHNSON AND PARKER	TX2510022.00	JOHN J MILES ET AL	4/20/1996
TX	HOOD, JOHNSON AND SOMERVELL	TX2210006.07	WALTER E PARKER ET AL	2/20/2003	HOOD	1917	324	8589
TX	HOOD, JOHNSON AND SOMERVELL	TX2210006.07	WALTER E PARKER ET AL	2/20/2003	JOHNSON	3040	609	34443
TX	HOOD, JOHNSON AND SOMERVELL	TX2210006.07	WALTER E PARKER ET AL	2/20/2003	SOMERVELL	110	183	15685
TX	HOOD, JOHNSON AND SOMERVELL	TX2210006.08	CAULTHROPE S HINTON ET UX	6/10/2003	HOOD	1939	515	13043
TX	HOOD, JOHNSON AND SOMERVELL	TX2210006.08	CAULTHROPE S HINTON ET UX	6/10/2003	JOHNSON	3114	593	28538
TX	HOOD, JOHNSON AND SOMERVELL	TX2210006.08	CAULTHROPE S HINTON ET UX	6/10/2003	SOMERVELL	115	251	35324
TX	HOOD AND SOMERVELL	TX2210017.01	STETSON MASSEY JR ET AL	5/6/2003	SOMERVELL	111	329	34633
TX	HOOD AND SOMERVELL	TX2210017.01	STETSON MASSEY JR ET AL	5/6/2003	HOOD	1917	321	8588
TX	HOOD AND SOMERVELL	TX2210017.01	STETSON MASSEY JR ET AL	5/6/2003
TX	HOOD AND SOMERVELL	TX2210017.01	STETSON MASSEY JR ET AL	5/6/2003
TX	HOOD AND SOMERVELL	TX2210017.01	STETSON MASSEY JR ET AL	5/6/2003
TX	HOOD AND SOMERVELL	TX2210017.01	STETSON MASSEY JR ET AL	5/6/2003
TX	HOOD AND SOMERVELL	TX2210017.01	STETSON MASSEY JR ET AL	5/6/2003
TX	HOOD AND SOMERVELL	TX2210017.01	STETSON MASSEY JR ET AL	5/6/2003
TX	HOOD AND SOMERVELL	TX2210017.01	STETSON MASSEY JR ET AL	5/6/2003
TX	HOOD AND SOMERVELL	TX2210017.01	STETSON MASSEY JR ET AL	5/6/2003
TX	HOOD AND SOMERVELL	TX2210017.01	STETSON MASSEY JR ET AL	5/6/2003
TX	HOOD AND SOMERVELL	TX2210017.01	STETSON MASSEY JR ET AL	5/6/2003
TX	HOOD AND SOMERVELL	TX2210017.01	STETSON MASSEY JR ET AL	5/6/2003
TX	HOOD AND SOMERVELL	TX2210017.01	STETSON MASSEY JR ET AL	5/6/2003
TX	HOOD AND SOMERVELL	TX2210017.01	STETSON MASSEY JR ET AL	5/6/2003
TX	HOOD AND SOMERVELL	TX2210017.05	STEWART ROGER	4/29/2004	HOOD	2009	22	7849
TX	HOOD AND SOMERVELL	TX2210017.05	STEWART ROGER	4/29/2004	SOMERVELL
TX	HOOD AND SOMERVELL	TX2210017.07	JUDY OWENS	4/29/2004	HOOD	2009	30	7851
TX	HOOD AND SOMERVELL	TX2210017.07	JUDY OWENS	4/29/2004	SOMERVELL
TX	HOOD AND SOMERVELL	TX2210017.08	ROGER STEWART ET AL	4/29/2004	HOOD	2013	604	8693
TX	HOOD AND SOMERVELL	TX2210017.08	ROGER STEWART ET AL	4/29/2004	SOMERVELL
TX	HOOD AND SOMERVELL	TX2210017.09	WILLIAM H WILSON	5/29/2004	HOOD	2021	393	10444
TX	HOOD AND SOMERVELL	TX2210017.09	WILLIAM H WILSON	5/29/2004	SOMERVELL
TX	HOOD AND SOMERVELL	TX2210017.10	JEANETTE WAI IND & TRUSTEE	11/2/2004	HOOD	2059	771	19471
TX	HOOD AND SOMERVELL	TX2210017.10	JEANETTE WAI IND & TRUSTEE	11/2/2004	SOMERVELL	135	679	39281
TX	HOOD AND SOMERVELL	TX2210017.14	TEXAS OSAGE ROYALTY POOL	5/15/2008	HOOD	2408	482	10421
TX	HOOD AND SOMERVELL	TX2210017.14	TEXAS OSAGE ROYALTY POOL	5/15/2008	SOMERVELL			20081871
TX	HOOD AND SOMERVELL	TX2210017.15	WILLIAM RICHARD BUSH ET UX	8/6/2004	HOOD	2038	279	38427
TX	HOOD AND SOMERVELL	TX2210017.15	WILLIAM RICHARD BUSH ET UX	8/6/2004	SOMERVELL	131	424	14374
TX	HOOD AND SOMERVELL	TX2210017.15	WILLIAM RICHARD BUSH ET UX	8/6/2004
TX	HOOD AND SOMERVELL	TX2210017.16	BRYANT EDDY	5/12/2010	HOOD	2548	349	6138
TX	HOOD AND SOMERVELL	TX2210017.16	BRYANT EDDY	5/12/2010	SOMERVELL			20101048
TX	HOOD AND SOMERVELL	TX2210017.17	WILLIAM H WILSON	5/21/2010	HOOD			2010-0006519
TX	HOOD AND SOMERVELL	TX2210017.17	WILLIAM H WILSON	5/21/2010	SOMERVELL			20101045
TX	HOOD AND SOMERVELL	TX2210017.18	DENISE GROSS	5/28/2010	HOOD			2010-0006904
TX	HOOD AND SOMERVELL	TX2210017.18	DENISE GROSS	5/28/2010	SOMERVELL			20101098
TX	HOOD AND SOMERVELL	TX2210017.19	DOROTHY STEWART	5/28/2010	HOOD			2010-0006906
TX	HOOD AND SOMERVELL	TX2210017.19	DOROTHY STEWART	5/28/2010	SOMERVELL			20101100
TX	HOOD AND SOMERVELL	TX2210017.20	ROGER STEWART	5/28/2010	HOOD			2010-0006905
TX	HOOD AND SOMERVELL	TX2210017.20	ROGER STEWART	5/28/2010	SOMERVELL			20101099
TX	HOOD AND SOMERVELL	TX2210017.21	JOHNNIE FAYE HUGGINS	5/25/2010	HOOD			2010-0006520
TX	HOOD AND SOMERVELL	TX2210017.21	JOHNNIE FAYE HUGGINS	5/25/2010	SOMERVELL			20101046
TX	HOOD AND SOMERVELL	TX2210017.22	VICKI YU	5/14/2010	HOOD			2010-0006901
TX	HOOD AND SOMERVELL	TX2210017.22	VICKI YU	5/14/2010	SOMERVELL			20101095
TX	HOOD AND SOMERVELL	TX2210017.23	JEANETTE WAI	5/14/2010	HOOD			2010-0006902
TX	HOOD AND SOMERVELL	TX2210017.23	JEANETTE WAI	5/14/2010	SOMERVELL			20101096
TX	HOOD AND SOMERVELL	TX2210017.24	NORMA HULSEY TEMPLE	5/26/2010	HOOD			2010-0006907
TX	HOOD AND SOMERVELL	TX2210017.24	NORMA HULSEY TEMPLE	5/26/2010	SOMERVELL			20101101
TX	HOOD AND SOMERVELL	TX2210017.25	LORETTA QUON ENG	5/14/2010	HOOD			2010-0006903
TX	HOOD AND SOMERVELL	TX2210017.25	LORETTA QUON ENG	5/14/2010	SOMERVELL			20101097
TX	HOOD AND SOMERVELL	TX2210017.26	JUDY WOODALL	6/16/2010	HOOD			2010-0007753
TX	HOOD AND SOMERVELL	TX2210017.26	JUDY WOODALL	6/16/2010	SOMERVELL			20101197
TX	HOOD AND SOMERVELL	TX2210017.27	UNITED CHURCH OF GOD	5/12/2010	HOOD			2010-0009317
TX	HOOD AND SOMERVELL	TX2210017.27	UNITED CHURCH OF GOD	5/12/2010	SOMERVELL			20101439
TX	HOOD AND SOMERVELL	TX2210017.28	DEVON ENERGY PRODUCTION	10/26/2010	HOOD			2010-0013013
TX	HOOD AND SOMERVELL	TX2210017.28	DEVON ENERGY PRODUCTION	10/26/2010	SOMERVELL			20110086
TX	HOOD AND SOMERVELL	TX2210026.01	SADLER SHARRON KINNARD	5/23/2003	HOOD	1925	178	10090
TX	HOOD AND SOMERVELL	TX2210026.01	SADLER SHARRON KINNARD	5/23/2003	SOMERVELL	112	439	34835
TX	HOOD AND SOMERVELL	TX2210026.02	KINNARD JAKE DARLAN	5/23/2003	HOOD	1925	168	10089
TX	HOOD AND SOMERVELL	TX2210026.02	KINNARD JAKE DARLAN	5/23/2003	SOMERVELL	112	419	34833
TX	HOOD AND SOMERVELL	TX2210026.03	ROGERS SANDRA KAY KINNARD	5/23/2003	SOMERVELL	112	428	34834
TX	HOOD AND SOMERVELL	TX2210026.03	ROGERS SANDRA KAY KINNARD	5/23/2003	HOOD	1925	157	10088
TX	HOOD AND SOMERVELL	TX2210026.04	KINNARD DARRELL WAYNE	5/23/2003	HOOD	1925	188	10091
TX	HOOD AND SOMERVELL	TX2210026.04	KINNARD DARRELL WAYNE	5/23/2003	SOMERVELL	112	448	34836
TX	HOOD AND SOMERVELL	TX2210027.00	STINSON BYRON ET UX	5/30/2003	HOOD	1927	202	10495
TX	HOOD AND SOMERVELL	TX2210027.00	STINSON BYRON ET UX	5/30/2003	SOMERVELL	112	767	34897
TX	HOOD AND SOMERVELL	TX2210116.00	ST TX M-103312	10/7/2003	SOMERVELL	119	829	36232
TX	HOOD AND SOMERVELL	TX2210116.00	ST TX M-103312	10/7/2003	HOOD	1969	417	19797
TX	HOOD AND SOMERVELL	TX2210118.00	LINDI GRISSOM GRANGER ETAL	11/22/2003	HOOD	1980	579	1343
TX	HOOD AND SOMERVELL	TX2210118.00	LINDI GRISSOM GRANGER ETAL	11/22/2003	SOMERVELL	121	738	36585
TX	HOOD AND SOMERVELL	TX2211184.01	JANICE SUSAN HUGHES ET VIR	12/4/2007	HOOD	2419	603	13096
TX	HOOD AND SOMERVELL	TX2211184.01	JANICE SUSAN HUGHES ET VIR	12/4/2007	SOMERVELL			20080284
TX	HOOD, JOHNSON AND SOMERVELL	TX2510025.01	VIRGINIA L RINGLER IND/TRE	9/23/2003	JOHNSON	3160	282	36566
TX	HOOD, JOHNSON AND SOMERVELL	TX2510025.01	VIRGINIA L RINGLER IND/TRE	9/23/2003	SOMERVELL	117	843	35841
TX	HOOD, JOHNSON AND SOMERVELL	TX2510025.01	VIRGINIA L RINGLER IND/TRE	9/23/2003
TX	JOHNSON AND SOMERVELL	TX2510025.02	O'GRADY SIX O RANCH	1/14/2004	JOHNSON	3213	949	1907
TX	JOHNSON AND SOMERVELL	TX2510025.02	O'GRADY SIX O RANCH	1/14/2004	SOMERVELL	121	839	36600
TX	JOHNSON AND SOMERVELL	TX4250001.01	S GREGORY FAMILY LIMITED	3/6/2003	JOHNSON	3047	270	16842
TX	JOHNSON AND SOMERVELL	TX4250001.01	S GREGORY FAMILY LIMITED	3/6/2003	SOMERVELL	110	178	34442
TX	JOHNSON AND SOMERVELL	TX4250001.01	S GREGORY FAMILY LIMITED	3/6/2003
TX	SOMERVELL	TX4250001.02	LOUISE SIMONTON KEAN	7/31/2006	SOMERVELL			45341
TX	SOMERVELL	TX4250001.03	KATHERINE BUCHACA	7/19/2006	SOMERVELL			45342
TX	SOMERVELL	TX4250001.04	FREDERICK WAY JACKSON III	6/5/2008	SOMERVELL			20082117
TX	SOMERVELL	TX4250001.05	DONNA MARIE G SKJEVELAND	8/12/2009	SOMERVELL			20092238
TX	SOMERVELL	TX4250001.06	MEEGHAN G WEIDENMULLER	4/26/2010	SOMERVELL			20100910
TX	SOMERVELL	TX4250003.01	TED SHERWIN ARMSTRONG	1/10/2001	SOMERVELL	88	123	30116
TX	SOMERVELL	TX4250003.02	ROGER LEE ARMSTRONG ET UX	1/10/2001	SOMERVELL	88	119	30114
TX	SOMERVELL	TX4250003.03	JAMES NEAL ARMSTRONG ET UX	1/10/2001	SOMERVELL	88	117	30113
TX	SOMERVELL	TX4250003.04	GEO SANDLIN ET AL	12/16/2005	SOMERVELL			42738
TX	SOMERVELL	TX4250003.05	ROGER LEE ARMSTRONG ET UX	12/23/2005	SOMERVELL			42811
TX	SOMERVELL	TX4250003.06	TED SHERWIN ARMSTRONG	12/23/2005	SOMERVELL			42812
TX	SOMERVELL	TX4250003.07	JAMES NEAL ARMSTRONG ET UX	12/23/2005	SOMERVELL			42857
TX	SOMERVELL	TX4250003.08	JAMES CLYDE ARMSTRONG	1/10/2001	SOMERVELL	88	115	30112
TX	SOMERVELL	TX4250006.00	NANCY BRIDGES KEESE ET VIR	6/18/2001	SOMERVELL	91	387	30894
TX	SOMERVELL	TX4250006.00	NANCY BRIDGES KEESE ET VIR	6/18/2001
TX	SOMERVELL	TX4250006.00	NANCY BRIDGES KEESE ET VIR	6/18/2001
TX	JOHNSON AND SOMERVELL	TX4250008.00	REECE WHITE ET UX	3/8/2001	JOHNSON	3003	356	9112
TX	JOHNSON AND SOMERVELL	TX4250008.00	REECE WHITE ET UX	3/8/2001	SOMERVELL	88	127	30118
TX	SOMERVELL	TX4250009.00	SAM W WHITE	3/8/2001	SOMERVELL	88	129	30119
TX	SOMERVELL	TX4250012.02	RONDA SPARKS DURAN	7/14/2003	SOMERVELL	115	58	35278
TX	SOMERVELL	TX4250012.03	ROCKY SPARKS	7/14/2003	SOMERVELL	115	46	35275
TX	SOMERVELL	TX4250012.04	BOBBY BARKER WIDNER	5/21/2003	SOMERVELL	114	524	35179
TX	SOMERVELL	TX4250012.05	JOYCE COFFMAN	6/23/2003	SOMERVELL	114	521	35178
TX	SOMERVELL	TX4250012.05	JOYCE COFFMAN	6/23/2003
TX	SOMERVELL	TX4250012.05	JOYCE COFFMAN	6/23/2003
TX	SOMERVELL	TX4250012.05	JOYCE COFFMAN	6/23/2003
TX	SOMERVELL	TX4250012.05	JOYCE COFFMAN	6/23/2003
TX	SOMERVELL	TX4250012.05	JOYCE COFFMAN	6/23/2003
TX	SOMERVELL	TX4250012.06	GERALDINE GLOVER BROADBENT	7/22/2003	SOMERVELL	115	54	35277
TX	SOMERVELL	TX4250012.06	GERALDINE GLOVER BROADBENT	7/22/2003
TX	SOMERVELL	TX4250012.06	GERALDINE GLOVER BROADBENT	7/22/2003
TX	SOMERVELL	TX4250012.06	GERALDINE GLOVER BROADBENT	7/22/2003
TX	SOMERVELL	TX4250012.06	GERALDINE GLOVER BROADBENT	7/22/2003
TX	SOMERVELL	TX4250012.06	GERALDINE GLOVER BROADBENT	7/22/2003
TX	SOMERVELL	TX4250012.06	GERALDINE GLOVER BROADBENT	7/22/2003
TX	SOMERVELL	TX4250012.06	GERALDINE GLOVER BROADBENT	7/22/2003
TX	SOMERVELL	TX4250012.07	DAVID POTTER	7/22/2003	SOMERVELL	115	50	35276
TX	SOMERVELL	TX4250012.08	ORAN C BAKER	7/14/2003	SOMERVELL	115	42	35274
TX	SOMERVELL	TX4250012.09	YVONNE ANNETTE SHUMAN	7/22/2003	SOMERVELL	114	531	35181
TX	SOMERVELL	TX4250012.10	GEORGE BARKER MURPHY	7/18/2003	SOMERVELL	114	535	35182
TX	SOMERVELL	TX4250012.11	MACATEE TRUST A DTD 4-13-1994	7/22/2003	SOMERVELL	114	514	35176
TX	SOMERVELL	TX4250012.12	BEVERLY MOORE	7/14/2003	SOMERVELL	114	527	35180
TX	SOMERVELL	TX4250012.13	LOTA MURPHY FARQUHAR	7/21/2003	SOMERVELL	115	78	35283
TX	SOMERVELL	TX4250012.14	RICHARD WILSON BARKER	7/18/2003	SOMERVELL	115	74	35282
TX	SOMERVELL	TX4250012.15	JANIS BARKER BUCKNER	7/18/2003	SOMERVELL	115	70	35281
TX	SOMERVELL	TX4250012.16	MARY EVELYN BARKER VAUGHN	7/18/2003	SOMERVELL	115	66	35280
TX	SOMERVELL	TX4250012.17	BENNY GALE SPARKS	6/23/2003	SOMERVELL	115	62	35279
TX	SOMERVELL	TX4250012.18	BUNNY GAIL GRAY HASTINGS	7/20/2003	SOMERVELL	115	255	35325
TX	SOMERVELL	TX4250012.19	JIMMI DIANNA DARDEN	7/20/2003	SOMERVELL	115	259	35326
TX	SOMERVELL	TX4250012.20	GENNI LU LAPLANTE	7/20/2003	SOMERVELL	115	263	35327
TX	SOMERVELL	TX4250012.21	JAMES RODNEY GRAY	7/20/2003	SOMERVELL	116	220	35524
TX	SOMERVELL	TX4250012.22	EUGENIA LOCKER SANDERS	7/22/2003	SOMERVELL	116	224	35525
TX	SOMERVELL	TX4250012.22	EUGENIA LOCKER SANDERS	7/22/2003	SOMERVELL
TX	SOMERVELL	TX4250012.23	DENNIS LEE POTTER	7/22/2003	SOMERVELL	115	636	35407
TX	SOMERVELL	TX4250012.24	D FRANK HOWETH	8/29/2003	SOMERVELL	119	605	36177
TX	SOMERVELL	TX4250012.25	GREGORY C MURPHY ET UX	10/8/2003	SOMERVELL	118	829	36032
TX	SOMERVELL	TX4250012.26	EDA WALLIN	7/18/2003	SOMERVELL	117	568	35790
TX	SOMERVELL	TX4250012.27	CHRISTOPHER EUGENE MURPHY	10/8/2003	SOMERVELL	118	842	36037
TX	SOMERVELL	TX4250012.28	CHEYENNE HILLS/GLEN ROSE	1/15/2004	SOMERVELL	122	278	36694
TX	SOMERVELL	TX4250012.29	CHEYENNE HILLS/GLEN ROSE	1/15/2004	SOMERVELL	122	273	36693
TX	SOMERVELL	TX4250012.30	JEFFREY C MCPHERSON ET UX	1/14/2004	SOMERVELL	122	838	36817
TX	SOMERVELL	TX4250012.31	WALLACE M MCPHERSON ET UX	1/29/2004	SOMERVELL	123	142	36860
TX	SOMERVELL	TX4250012.32	LEON LANGFORD	6/5/2004	SOMERVELL	128	339	37840
TX	SOMERVELL	TX4250012.33	CAROLYN LANGFORD HENARD	6/5/2004	SOMERVELL	128	348	37843
TX	SOMERVELL	TX4250012.34	DELVIN LANGFORD	6/5/2004	SOMERVELL	128	597	37894
TX	SOMERVELL	TX4250012.35	UNA ANN BARKER	6/26/2004	SOMERVELL	129	482	38062
TX	SOMERVELL	TX4250012.36	LESLIE DEE HARRELSON	7/27/2004	SOMERVELL	130	619	38298
TX	SOMERVELL	TX4250012.37	BOBBIE R LAFLEUR	12/7/2004	SOMERVELL	137	1	39515
TX	SOMERVELL	TX4250012.37	BOBBIE R LAFLEUR	12/7/2004
TX	SOMERVELL	TX4250012.38	DOLLY ANITA MOSS OLSEN	4/3/2007	SOMERVELL			20071307
TX	SOMERVELL	TX4250012.39	JAMES R MOSS	4/3/2007	SOMERVELL			20071306
TX	SOMERVELL	TX4250012.40	JERIS ANN MOSS	4/3/2007	SOMERVELL			20071305
TX	SOMERVELL	TX4250012.41	JERRY GLENDON MOSS	4/3/2007	SOMERVELL			20071308
TX	SOMERVELL	TX4250012.42	MICHAEL MOSS	4/3/2007	SOMERVELL			20071403
TX	SOMERVELL	TX4250012.49	CYNTHIA LAVERNE NEWSOME	8/25/2008	SOMERVELL			20082370
TX	SOMERVELL	TX4250012.50	SHARON W DODSON	8/25/2008	SOMERVELL			20082371
TX	SOMERVELL	TX4250012.52	IRA E POTTER	1/21/2009	SOMERVELL			20090463
TX	SOMERVELL	TX4250012.53	DANIEL T WILDER ET UX	9/24/2006	SOMERVELL			45734
TX	SOMERVELL	TX4250013.00	DOUGLAS D DUGGER ET UX	4/16/2003	SOMERVELL	111	84	34590
TX	SOMERVELL	TX4250014.01	JAMES R HEWLETT	4/29/2003	SOMERVELL	111	93	34593
TX	SOMERVELL	TX4250015.00	PHIL A DUGGER	4/16/2003	SOMERVELL	111	90	34592
TX	SOMERVELL	TX4250016.01	THOMAS L DUGGER ET UX	4/16/2003	SOMERVELL	111	87	34591
TX	SOMERVELL	TX4250016.02	BANK OF AMERICA NA	2/8/2008	SOMERVELL			20080495
TX	SOMERVELL	TX4250016.02	BANK OF AMERICA NA	2/8/2008	HOOD	2378	329
TX	SOMERVELL	TX4250016.03	PHIL A DUGGER	10/6/2006	SOMERVELL			46007
TX	SOMERVELL	TX4250016.04	CHGR PROPERTIES	3/26/2008	SOMERVELL			20081118
TX	SOMERVELL	TX4250016.05	DENNY L DEHAVEN ET UX	4/23/2008	SOMERVELL			20081260
TX	SOMERVELL	TX4250016.06	DAN OSBORNE ET UX	5/16/2003	SOMERVELL	111	78	34588
TX	SOMERVELL	TX4250016.07	J RUSSELL KELLEY ET UX	2/13/2008	SOMERVELL			20080660
TX	SOMERVELL	TX4250017.00	BOB HARRIS OIL COMPANY	5/29/2003	SOMERVELL	111	778	34714
TX	SOMERVELL	TX4250017.00	BOB HARRIS OIL COMPANY	5/29/2003
TX	SOMERVELL	TX4250017.00	BOB HARRIS OIL COMPANY	5/29/2003
TX	SOMERVELL	TX4250018.01	SEALY & SMITH FOUNDATION	4/9/2003	SOMERVELL	110	188	34444
TX	SOMERVELL	TX4250018.01	SEALY & SMITH FOUNDATION	4/9/2003
TX	SOMERVELL	TX4250018.01	SEALY & SMITH FOUNDATION	4/9/2003
TX	SOMERVELL	TX4250018.01	SEALY & SMITH FOUNDATION	4/9/2003
TX	SOMERVELL	TX4250018.01	SEALY & SMITH FOUNDATION	4/9/2003
TX	SOMERVELL	TX4250018.01	SEALY & SMITH FOUNDATION	4/9/2003
TX	SOMERVELL	TX4250018.01	SEALY & SMITH FOUNDATION	4/9/2003
TX	SOMERVELL	TX4250018.01	SEALY & SMITH FOUNDATION	4/9/2003
TX	SOMERVELL	TX4250018.05	DAN MCCARTY IND & INDEP EX	12/9/2003	SOMERVELL	121	715	36576
TX	SOMERVELL	TX4250018.05	DAN MCCARTY IND & INDEP EX	12/9/2003
TX	SOMERVELL	TX4250018.05	DAN MCCARTY IND & INDEP EX	12/9/2003
TX	SOMERVELL	TX4250018.05	DAN MCCARTY IND & INDEP EX	12/9/2003
TX	SOMERVELL	TX4250018.05	DAN MCCARTY IND & INDEP EX	12/9/2003
TX	SOMERVELL	TX4250018.05	DAN MCCARTY IND & INDEP EX	12/9/2003
TX	SOMERVELL	TX4250018.05	DAN MCCARTY IND & INDEP EX	12/9/2003
TX	SOMERVELL	TX4250018.05	DAN MCCARTY IND & INDEP EX	12/9/2003
TX	SOMERVELL	TX4250018.08	DAN MCCARTY	1/27/2004	SOMERVELL	122	844	36820
TX	SOMERVELL	TX4250018.0B	RICHARD BRYAN MILLER	5/6/2009	SOMERVELL			20091149
TX	SOMERVELL	TX4250018.0D	AUBREY MCFARREN TR	5/26/2009	SOMERVELL			20091047
TX	SOMERVELL	TX4250018.0E	MARGARET LEE FRASER TR	6/2/2009	SOMERVELL			20091147
TX	SOMERVELL	TX4250018.0F	MARY A WHILDEN TR	5/26/2009	SOMERVELL			20091146
TX	SOMERVELL	TX4250018.0G	JOANN M ANDERSON	5/20/2009	SOMERVELL			20091142
TX	SOMERVELL	TX4250018.0H	JAMES E BRADY ET UX	6/19/2009	SOMERVELL			20091361
TX	SOMERVELL	TX4250018.0H	JAMES E BRADY ET UX	6/19/2009
TX	SOMERVELL	TX4250018.0I	BRADY CREEK LLC	6/19/2009	SOMERVELL			20091740
TX	SOMERVELL	TX4250018.0I	BRADY CREEK LLC	6/19/2009
TX	SOMERVELL	TX4250018.0K	MERLE L WALDEN ET UX	7/21/2009	SOMERVELL			20091503
TX	SOMERVELL	TX4250018.0O	DAVID CRISP ET UX	11/5/2009	SOMERVELL			20092240
TX	SOMERVELL	TX4250018.0P	JOE E HUFFMAN ET UX	11/11/2009	SOMERVELL			20092268
TX	SOMERVELL	TX4250018.0Q	DYRELL F DAVIS JR ET UX	11/9/2009	SOMERVELL			20092239
TX	SOMERVELL	TX4250018.0R	MICHAEL R DOUGLAS ET UX	11/12/2009	SOMERVELL			20092422
TX	SOMERVELL	TX4250018.0S	STUART L MANN	1/2/2009	SOMERVELL			20092270
TX	SOMERVELL	TX4250018.0T	THOMAS J BEAUDIN ET UX	11/19/2009	SOMERVELL			20092421
TX	SOMERVELL	TX4250018.0U	RICHARD D TROTTER ET UX	11/4/2009	SOMERVELL			20092312
TX	SOMERVELL	TX4250018.0V	DINOSAUR VALLEY CONSTR INC	12/2/2009	SOMERVELL			20092293
TX	SOMERVELL	TX4250018.0W	WAYNE E HAWKINS SR	11/17/2009	SOMERVELL			20092292
TX	SOMERVELL	TX4250018.0X	JODIE F REYNOLDS	12/9/2009	SOMERVELL			20092419
TX	SOMERVELL	TX4250018.0Y	RICHARD REYNOLDS ET UX	12/16/2009	SOMERVELL			20092420
TX	SOMERVELL	TX4250018.0Z	WAYNE E HAWKINS JR	11/17/2009	SOMERVELL			20092378
TX	SOMERVELL	TX4250018.12	JOE HUFFMAN ET UX	5/24/2005	SOMERVELL	144	259	41016
TX	SOMERVELL	TX4250018.14	PAUL U THOMPSON ET UX	6/7/2005	SOMERVELL	144	243	41011
TX	SOMERVELL	TX4250018.14	PAUL U THOMPSON ET UX	6/7/2005
TX	SOMERVELL	TX4250018.15	ANTONY W MABERRY ET UX	5/17/2005	SOMERVELL	144	240	41010
TX	SOMERVELL	TX4250018.16	DAVID L KATTNER ET UX	6/2/2005	SOMERVELL	144	237	41009
TX	SOMERVELL	TX4250018.17	DAVID L PARSONS ET UX	6/7/2005	SOMERVELL	144	228	41006
TX	SOMERVELL	TX4250018.18	ELIZABETH A PARHAM	6/7/2005	SOMERVELL	144	223	41004
TX	SOMERVELL	TX4250018.19	DONNA BOYD IND & EXE/ADMIN	6/13/2005	SOMERVELL	144	220	41003
TX	SOMERVELL	TX4250018.1A	DAVID B DUDIK ET UX	12/1/2009	SOMERVELL			20092345
TX	SOMERVELL	TX4250018.1B	JOE E HUFFMAN ET UX	12/3/2009	SOMERVELL			20092294
TX	SOMERVELL	TX4250018.1C	CHARLES A HARRISON JR	12/16/2009	SOMERVELL			20100017
TX	SOMERVELL	TX4250018.1D	EDDIE STROUD ET UX	12/9/2009	SOMERVELL			20100061
TX	SOMERVELL	TX4250018.1E	RICHARD A NEILL ET UX	1/14/2010	SOMERVELL			20100121
TX	SOMERVELL	TX4250018.1F	MIKE LINKER ET UX	3/15/2010	SOMERVELL			20100640
TX	SOMERVELL	TX4250018.1I	JOYCE KELSO LEE	8/10/2010	SOMERVELL			20101567
TX	SOMERVELL	TX4250018.1J	BETTY MARS ET VIR	9/21/2010	SOMERVELL			20101701
TX	SOMERVELL	TX4250018.1K	BARBARA ELOISE EVANS	9/13/2010	SOMERVELL			20101702
TX	SOMERVELL	TX4250018.1L	PAULINE MEARS	9/10/2010	SOMERVELL			20101703
TX	SOMERVELL	TX4250018.1M	HENRY W BLACKWELL ET UX	9/8/2010	SOMERVELL			20101704
TX	SOMERVELL	TX4250018.1N	CLODELL DAVIS	9/13/2010	SOMERVELL			20101705
TX	SOMERVELL	TX4250018.1O	BILLIE KEENUM ROBERSON	8/31/2010	SOMERVELL			20101708
TX	SOMERVELL	TX4250018.1P	SONDRA M HEATON	8/31/2010	SOMERVELL			20101707
TX	SOMERVELL	TX4250018.1Q	RUTH K VAN NOSTRAND ET VIR	8/25/2010	SOMERVELL			20101700
TX	SOMERVELL	TX4250018.1R	GEORGE KEENUM	9/12/2010	SOMERVELL			20101699
TX	SOMERVELL	TX4250018.1S	GARY W BLACKWELL	9/9/2010	SOMERVELL			20101753
TX	SOMERVELL	TX4250018.1U	D GARTRELL IND/AIF A YZAGUIRRE	10/1/2010	SOMERVELL			20101800
TX	SOMERVELL	TX4250018.1V	WAYNE C GRAHAM ET UX	9/28/2010	SOMERVELL			20101803
TX	SOMERVELL	TX4250018.1X	MILDRED MORRIS	9/28/2010	SOMERVELL			20101831
TX	SOMERVELL	TX4250018.1Y	DOYLE GRAHAM	9/28/2010	SOMERVELL			20101804
TX	SOMERVELL	TX4250018.1Z	JOYCE CAROL GRAHAM MCCULLAR	9/28/2010	SOMERVELL			20101805
TX	SOMERVELL	TX4250018.20	LES M BRANDENBURG ET UX	6/28/2005	SOMERVELL	145	599	41254
TX	SOMERVELL	TX4250018.21	STEVE PECK & THERESA PECK	7/14/2005	SOMERVELL	145	610	41258
TX	SOMERVELL	TX4250018.23	MICHAEL W BUSCH ET UX	7/19/2005	SOMERVELL	147	648	41635
TX	SOMERVELL	TX4250018.24	RONALD VANN STANFORD ET UX	7/27/2005	SOMERVELL	147	601	41621
TX	SOMERVELL	TX4250018.25	GLEN F WILLIAMS II ET UX	7/27/2005	SOMERVELL	147	604	41622
TX	SOMERVELL	TX4250018.26	DWAYNE GRIFFIN ET UX	8/1/2005	SOMERVELL	147	607	41623
TX	SOMERVELL	TX4250018.27	WILLIAM D CLEVELAND ET UX	7/21/2005	SOMERVELL			41910
TX	SOMERVELL	TX4250018.2A	BETTY ANN GRAHAM	9/27/2010	SOMERVELL			20101806
TX	SOMERVELL	TX4250018.2B	DOROTHY MUSE COX	9/27/2010	SOMERVELL			20101807
TX	SOMERVELL	TX4250018.2C	VIVIA E DITMORE ET VIR	9/28/2010	SOMERVELL			20101808
TX	SOMERVELL	TX4250018.2D	WALTER LEONARD HOOD	9/27/2010	SOMERVELL			20101833
TX	SOMERVELL	TX4250018.2E	ROBBIE GOODE TIDWELL	9/27/2010	SOMERVELL			20101914
TX	SOMERVELL	TX4250018.2F	BILLIE C GOODE ET UX	9/27/2010	SOMERVELL			20101913
TX	SOMERVELL	TX4250018.2G	CLOYCE LITTLE	10/23/2010	SOMERVELL			20101911
TX	SOMERVELL	TX4250018.2H	HIRSE L GRAHAM	9/28/2010	SOMERVELL			20101912
TX	SOMERVELL	TX4250018.2J	GLADYS MAYHAR	9/25/2010	SOMERVELL			20101910
TX	SOMERVELL	TX4250018.2K	CAROL ANN GRAHAM	9/28/2010	SOMERVELL			20101909
TX	SOMERVELL	TX4250018.2L	WYATT FAMILY PTNSHP LTD	10/12/2010	SOMERVELL			20101900
TX	SOMERVELL	TX4250018.2L	WYATT FAMILY PTNSHP LTD	10/12/2010
TX	SOMERVELL	TX4250018.2L	WYATT FAMILY PTNSHP LTD	10/12/2010
TX	SOMERVELL	TX4250018.2L	WYATT FAMILY PTNSHP LTD	10/12/2010
TX	SOMERVELL	TX4250018.2M	LEVONA GRAHAM MACON ET VIR	9/28/2010	SOMERVELL			20101902
TX	SOMERVELL	TX4250018.2N	R D FORD	11/3/2010	SOMERVELL			20101903
TX	SOMERVELL	TX4250018.2O	RUBY MUSE MARTIN	10/19/2010	SOMERVELL			20101904
TX	SOMERVELL	TX4250018.2P	WILLIAM E HAWKINS ET UX	9/14/2010	SOMERVELL			20101905
TX	SOMERVELL	TX4250018.2Q	BILLIE J LITTLE	10/26/2010	SOMERVELL			20101953
TX	SOMERVELL	TX4250018.2R	MARK LITTLE	11/5/2010	SOMERVELL			20101954
TX	SOMERVELL	TX4250018.2S	SHERRY AMYX	11/5/2010	SOMERVELL			20101955
TX	SOMERVELL	TX4250018.2T	ARMENTHA C MARTIN	11/4/2010	SOMERVELL			20101995
TX	SOMERVELL	TX4250018.2U	JOHN W POOL	11/23/2010	SOMERVELL			20101992
TX	SOMERVELL	TX4250018.2V	FARRIS R GARTRELL ET UX	12/7/2010	SOMERVELL			20102058
TX	SOMERVELL	TX4250018.2W	PETER W MUNSTERMAN ET UX	10/25/2010	SOMERVELL			20102057
TX	SOMERVELL	TX4250018.2X	MICHAEL W MUNSTERMAN ET UX	10/25/2010	SOMERVELL			20102059
TX	SOMERVELL	TX4250018.2Y	WILLIAM H MUNSTERMAN ET UX	10/25/2010	SOMERVELL			20102060
TX	SOMERVELL	TX4250018.2Z	JOHN W MUNSTERMAN	10/25/2010	SOMERVELL			20102061
TX	SOMERVELL	TX4250018.30	RONNIE G LONG ET UX	10/12/2005	SOMERVELL			42597
TX	SOMERVELL	TX4250018.31	C S HARRINGTON III ET UX	10/29/2005	SOMERVELL			43676
TX	SOMERVELL	TX4250018.32	JIMMY L ROACH ET EX / VLB	10/25/2005	SOMERVELL			43100
TX	SOMERVELL	TX4250018.33	JEFF RIGANO ET UX	1/10/2006	SOMERVELL			43044
TX	SOMERVELL	TX4250018.34	JEFFREY O HANSEN ET UX	1/10/2006	SOMERVELL			43043
TX	SOMERVELL	TX4250018.36	KEVIN DAMRON ET UX	1/13/2006	SOMERVELL			43305
TX	SOMERVELL	TX4250018.37	ERNEST F GASS ET UX	1/25/2006	SOMERVELL			43306
TX	SOMERVELL	TX4250018.38	TRACY JOLENE VAUGHN	1/13/2006	SOMERVELL			43300
TX	SOMERVELL	TX4250018.3A	CHARLES LITTLE	11/16/2010	SOMERVELL			20102097
TX	SOMERVELL	TX4250018.3B	JAMES LITTLE	12/9/2010	SOMERVELL			20102099
TX	SOMERVELL	TX4250018.3C	VICKI OAKES	12/13/2010	SOMERVELL			20102137
TX	SOMERVELL	TX4250018.3D	PHILLIP M DAVID ET UX	12/9/2010	SOMERVELL			20102140
TX	SOMERVELL	TX4250018.3E	KENNETH LITTLE	12/20/2010	SOMERVELL			20110081
TX	SOMERVELL	TX4250018.3F	WILLENE D KEENUM	12/10/2010	SOMERVELL			20110080
TX	SOMERVELL	TX4250018.3G	JO ANNA NORMAN	12/15/2010	SOMERVELL			20110079
TX	SOMERVELL	TX4250018.3H	J M LITTLE	12/10/2010	SOMERVELL			20110134
TX	SOMERVELL	TX4250018.3J	HOLLY BARR GEORGE	10/25/2010	SOMERVELL			20110229
TX	SOMERVELL	TX4250018.3K	SHELLI BARR	10/25/2010	SOMERVELL			20110228
TX	SOMERVELL	TX4250018.3L	FRANCES MELINDA ROSSER	10/25/2010	SOMERVELL			20110230
TX	SOMERVELL	TX4250018.3O	KIMBERLY LITTLE	12/30/2010	SOMERVELL			20110595
TX	SOMERVELL	TX4250018.3P	CAL FARLEYS BOYS RANCH	1/28/2011	SOMERVELL			20110519
TX	SOMERVELL	TX4250018.3Q	OWEN EUGENE BUSH	4/4/2011	SOMERVELL			20110718
TX	SOMERVELL	TX4250018.3R	WAYNE S CAMPBELL JR ET UX	4/7/2011	SOMERVELL			20110710
TX	SOMERVELL	TX4250018.3S	SHAWNA LITTLE	3/8/2011	SOMERVELL			20110711
TX	SOMERVELL	TX4250018.3T	SHELLY D LITTLE	3/8/2011	SOMERVELL			20110713
TX	SOMERVELL	TX4250018.3U	LOYD L LEWIS ET UX	4/25/2011	SOMERVELL			20110959
TX	SOMERVELL	TX4250018.3V	WHITNEY MARSHALL PERRY	4/11/2011	SOMERVELL			20110956
TX	SOMERVELL	TX4250018.3W	MERLE EDWARD DOSS JR	4/27/2011	SOMERVELL			20110955
TX	SOMERVELL	TX4250018.3X	ASHLEY MARSHALL EVERETT	5/17/2011	SOMERVELL			20111069
TX	SOMERVELL	TX4250018.3Z	WILLIAM N HARMON ET UX	7/11/2011	SOMERVELL			20111443
TX	SOMERVELL	TX4250018.43	FLOYD DARRELL BAKER ET UX	2/27/2007	SOMERVELL			20070689
TX	SOMERVELL	TX4250018.47	PATSY S MOORE FAMILY TRUST	3/15/2006	SOMERVELL			44827
TX	SOMERVELL	TX4250018.47	PATSY S MOORE FAMILY TRUST	3/15/2006
TX	SOMERVELL	TX4250018.48	J H WEIR II	5/9/2006	SOMERVELL			44830
TX	SOMERVELL	TX4250018.49	MITCHELL D WEIR	5/9/2006	SOMERVELL			44829
TX	SOMERVELL	TX4250018.4A	WYATT FAMILY PARTNERSHIP LTD	8/17/2011	SOMERVELL			20111545
TX	SOMERVELL	TX4250018.4B	SCHMIDT FAMILY TRUST	8/29/2011	SOMERVELL			20111728
TX	SOMERVELL	TX4250018.4C	BLAINE E STROUD ET UX	8/24/2011	SOMERVELL			20111628
TX	SOMERVELL	TX4250018.4D	REVIS F PARKISON ET UX	9/9/2011	SOMERVELL			20111797
TX	SOMERVELL	TX4250018.4E	JOYCE KELSO LEE	10/21/2011	SOMERVELL			20112005
TX	SOMERVELL	TX4250018.4I	C C BALLARD HOLDINGS LLC	6/11/2014	SOMERVELL			20140990
TX	SOMERVELL	TX4250018.4J	PINCKNEY M SMITH ET UX	6/26/2014	SOMERVELL			20141067
TX	SOMERVELL	TX4250018.4K	WINDFALL RANCH LTD	6/26/2014	SOMERVELL			20141066
TX	SOMERVELL	TX4250018.4L	JAMES L PATTON ET UX	7/23/2014	SOMERVELL			20141795
TX	SOMERVELL	TX4250018.4M	HUGH M SMITH	8/9/2014	SOMERVELL			20141532
TX	SOMERVELL	TX4250018.4N	CHAD A THIGPEN ET UX	7/24/2014	SOMERVELL			20141536
TX	SOMERVELL	TX4250018.4P	RICHARD TALAVERA ET UX	7/24/2014	SOMERVELL			20141975
TX	SOMERVELL	TX4250018.4Q	DB BARNETT LP	1/29/2015	SOMERVELL			20150550
TX	SOMERVELL	TX4250018.50	SHEA WEIR ZIMMERMAN	5/9/2006	SOMERVELL			44831
TX	SOMERVELL	TX4250018.51	JAY C WEIR	5/9/2006	SOMERVELL			44828
TX	SOMERVELL	TX4250018.91	ALICIA S ALLEN	7/29/2008	SOMERVELL			20082553
TX	SOMERVELL	TX4250018.92	LARRY P SMITH	10/8/2008	SOMERVELL			20101195
TX	SOMERVELL	TX4250018.92	LARRY P SMITH	10/8/2008	HOOD	2443	3	18698
TX	SOMERVELL	TX4250018.96	BILL E WARD	1/30/2009	SOMERVELL			20090464
TX	SOMERVELL	TX4250018.97	MARTHA CAROLYN HOODENPYLE	2/24/2009	SOMERVELL			20090717
TX	SOMERVELL	TX4250018.98	GROVER R DOWNING ET UX	2/18/2009	SOMERVELL			20090623
TX	SOMERVELL	TX4250018.99	FRED M ROBERTS ET UX	2/17/2009	SOMERVELL			20090670
TX	SOMERVELL	TX4250019.00	HELEN J VAUGHN IND & INDEP	5/23/2003	SOMERVELL	111	332	34634
TX	SOMERVELL	TX4250019.00	HELEN J VAUGHN IND & INDEP	5/23/2003
TX	SOMERVELL	TX4250020.01	CIRCLE W PARTNERS	6/2/2003	SOMERVELL	112	214	34783
TX	SOMERVELL	TX4250020.01	CIRCLE W PARTNERS	6/2/2003
TX	SOMERVELL	TX4250020.02	CHARLES LOCKETT	4/9/2007	SOMERVELL			20071302
TX	SOMERVELL	TX4250020.03	JAMES L TAYLOR ET UX	4/8/2007	SOMERVELL			20071309
TX	SOMERVELL	TX4250020.04	PAUL EDWARD HALL ET UX	4/16/2007	SOMERVELL			20071400
TX	SOMERVELL	TX4250020.05	WALTER DON PHIPPS	4/23/2007	SOMERVELL			20071404
TX	SOMERVELL	TX4250020.06	GLENDA ADELL GRAHAM	4/30/2007	SOMERVELL			20071691
TX	SOMERVELL	TX4250020.07	JAMES RUSSELL WILLIAMS	4/30/2007	SOMERVELL			20071686
TX	SOMERVELL	TX4250020.08	BRENDA SUE REAGAN	4/30/2007	SOMERVELL			20071690
TX	SOMERVELL	TX4250020.09	MARY MCKINNEY PLUMMER	4/9/2007	SOMERVELL			20071682
TX	SOMERVELL	TX4250020.10	PATSY LORENE BUSH	4/30/2007	SOMERVELL			20071687
TX	SOMERVELL	TX4250020.11	DURED E WHEATLEY	4/26/2007	SOMERVELL			20071688
TX	SOMERVELL	TX4250020.12	EDITH M WHEATLEY RICH	5/8/2007	SOMERVELL			20071692
TX	SOMERVELL	TX4250020.13	EUNICE AILENE STRICKLAND	4/30/2007	SOMERVELL			20071689
TX	SOMERVELL	TX4250020.14	BRENDA RYDER STURM	5/21/2007	SOMERVELL			20071679
TX	SOMERVELL	TX4250020.15	EDYTH LORIE BRIDGES BY BEL	4/18/2007	SOMERVELL			20071678
TX	SOMERVELL	TX4250020.16	LEIGH RYDER LEAMING	5/21/2007	SOMERVELL			20071882
TX	SOMERVELL	TX4250020.17	BILLIE D WHEATLEY BENNETT	4/20/2007	SOMERVELL			20071881
TX	SOMERVELL	TX4250020.18	WILLA DEAN REECE	4/30/2007	SOMERVELL			20071879
TX	SOMERVELL	TX4250020.19	CINDY CONNER	5/14/2007	SOMERVELL			20071880
TX	SOMERVELL	TX4250020.20	TED RYDER	5/21/2007	SOMERVELL			20071878
TX	SOMERVELL	TX4250020.21	NORMA JEAN WHEATLEY COX	4/23/2007	SOMERVELL			20071876
TX	SOMERVELL	TX4250020.22	DANNY RAY COTTON	5/23/2007	SOMERVELL			20071875
TX	SOMERVELL	TX4250020.23	LINDA RYDER DUGGAN	5/21/2007	SOMERVELL			20071877
TX	SOMERVELL	TX4250020.24	PEGGY COTTON JELEN	5/23/2007	SOMERVELL			20072018
TX	SOMERVELL	TX4250020.25	DAVE RYDER	5/21/2007	SOMERVELL			20072212
TX	SOMERVELL	TX4250020.26	ROSALIND M MURPHY	6/14/2007	SOMERVELL			20072022
TX	SOMERVELL	TX4250020.27	MURRAY PLUMMER WHEATLEY	7/16/2007	SOMERVELL			20072188
TX	SOMERVELL	TX4250020.28	DAVID GLYNN MCKINNEY	10/5/2007	SOMERVELL			20072980
TX	SOMERVELL	TX4250020.28	DAVID GLYNN MCKINNEY	10/5/2007	HOOD	2343	555	18692
TX	SOMERVELL	TX4250020.29	JACKIE DWAIN WILLIAMS	2/16/2008	SOMERVELL			20080713
TX	SOMERVELL	TX4250020.30	MARILYN ANN GODINEZ	4/29/2011	SOMERVELL			20111050
TX	SOMERVELL	TX4250021.00	JIMMIE DOYLE BRANHAM ET UX	6/18/2003	SOMERVELL	112	211	34782
TX	HOOD AND SOMERVELL	TX4250026.00	PERRY J ADAMS ET UX	6/23/2003	SOMERVELL	112	765	34896
TX	HOOD AND SOMERVELL	TX4250026.00	PERRY J ADAMS ET UX	6/23/2003	HOOD	1927	200	10494
TX	HOOD AND SOMERVELL	TX4250026.00	PERRY J ADAMS ET UX	6/23/2003
TX	HOOD AND SOMERVELL	TX4250039.00	ALYCIA R PROCTER LIVING TR	7/9/2003	HOOD	1937	594	12649
TX	HOOD AND SOMERVELL	TX4250039.00	ALYCIA R PROCTER LIVING TR	7/9/2003	SOMERVELL	115	40	35273
TX	SOMERVELL	TX4250041.00	REBECCA BROWN KELLER	7/28/2003	SOMERVELL	115	91	35288
TX	SOMERVELL	TX4250041.00	REBECCA BROWN KELLER	7/28/2003
TX	SOMERVELL	TX4250053.03	WANDA R MORRIS	4/15/2008	SOMERVELL			20081716
TX	SOMERVELL	TX4250053.04	PATRICIA REUPKE	4/15/2008	SOMERVELL			20081715
TX	SOMERVELL	TX4250053.05	SHERRIE LEIGH VOGEL ET VIR	4/15/2008	SOMERVELL			20081855
TX	SOMERVELL	TX4250053.06	SHIRLEY EATON	4/15/2008	SOMERVELL			20081854
TX	SOMERVELL	TX4250053.06	SHIRLEY EATON	4/15/2008
TX	SOMERVELL	TX4250053.06	SHIRLEY EATON	4/15/2008
TX	SOMERVELL	TX4250053.07	FRANKIE V OTIS	4/15/2008	SOMERVELL			20081712
TX	SOMERVELL	TX4250053.08	SARAH ROTHCHILD	4/15/2008	SOMERVELL			20081862
TX	SOMERVELL	TX4250053.09	TERESA M LAVERGNE ET VIR	4/15/2008	SOMERVELL			20081923
TX	SOMERVELL	TX4250053.13	B YOLANDA BUNT	4/15/2008	SOMERVELL			20081922
TX	SOMERVELL	TX4250053.14	SONJA LYLES ET VIR	4/15/2008	SOMERVELL			20081937
TX	SOMERVELL	TX4250053.15	ROYJELENE B STUMP	4/15/2008	SOMERVELL			20081938
TX	SOMERVELL	TX4250053.16	ANTHONY RAPPE ET UX	4/15/2008	SOMERVELL			20081939
TX	SOMERVELL	TX4250053.17	SUE ELLA MCFALL	4/15/2008	SOMERVELL			20082110
TX	SOMERVELL	TX4250053.18	PAUL TROXELL HEBERT	5/22/2008	HOOD	2433	312	16305
TX	SOMERVELL	TX4250053.18	PAUL TROXELL HEBERT	5/22/2008	SOMERVELL			20091682
TX	SOMERVELL	TX4250053.37	MONA KELLOGG	6/29/2011	SOMERVELL			20111723
TX	SOMERVELL	TX4250055.14	MARK MUNDEN	9/18/2011	SOMERVELL			20111849
TX	SOMERVELL	TX4250055.15	NANCY MUNDEN	9/18/2011	SOMERVELL			20111850
TX	SOMERVELL	TX4250055.16	JEFFERY SCOTT MCMILLAN	9/20/2011	SOMERVELL			20111861
TX	SOMERVELL	TX4250055.17	MARY SUZANNE MCMILLAN ET VIR	9/20/2011	SOMERVELL			20111860
TX	SOMERVELL	TX4250056.01	LEROY HENRY HODGKINSON	8/20/2003	SOMERVELL	116	218	35523
TX	SOMERVELL	TX4250056.01	LEROY HENRY HODGKINSON	8/20/2003
TX	SOMERVELL	TX4250056.02	ROBERT LEE MERRILL ET UX	11/10/2011	SOMERVELL			20112072
TX	SOMERVELL	TX4250060.00	JANET ELLEN MANN	8/21/2003	SOMERVELL	116	197	35516
TX	SOMERVELL	TX4250060.00	JANET ELLEN MANN	8/21/2003
TX	SOMERVELL	TX4250060.00	JANET ELLEN MANN	8/21/2003
TX	HOOD AND SOMERVELL	TX4250065.00	ROBERT KING ET UX	8/25/2003	SOMERVELL	117	23	35666
TX	HOOD AND SOMERVELL	TX4250065.00	ROBERT KING ET UX	8/25/2003	HOOD	1951	585	15657
TX	SOMERVELL	TX4250068.01	DURANT HERITAGE TR ET AL	7/17/2003	SOMERVELL	117	16	35664
TX	SOMERVELL	TX4250068.02	THE PROSPECT COMPANY	8/13/2003	SOMERVELL	117	14	35663
TX	SOMERVELL	TX4250068.03	DURANT HERITAGE TRUST A-1 ET AL	7/17/2003	SOMERVELL	117	11	35662
TX	SOMERVELL	TX4250068.03	DURANT HERITAGE TRUST A-1 ET AL	7/17/2003
TX	SOMERVELL	TX4250068.04	VERNER R SHURMON	4/13/2005	SOMERVELL	142	449	40593
TX	SOMERVELL	TX4250068.05	ROBERT V BAGWELL ET UX	4/13/2005	SOMERVELL	142	446	40592
TX	SOMERVELL	TX4250068.07	LARRY RICHARDSON ET UX	5/9/2005	SOMERVELL	142	474	40601
TX	SOMERVELL	TX4250068.08	FRED L CARTER ET UX	5/5/2005	SOMERVELL	143	28	40710
TX	SOMERVELL	TX4250068.09	DENNIS J CRABTREE ET UX	5/18/2005	SOMERVELL	143	47	40717
TX	SOMERVELL	TX4250068.13	WAYNE BRONNER ET UX	6/15/2005	SOMERVELL	145	602	41255
TX	SOMERVELL	TX4250068.14	JOHN A CROZIER ET UX	6/16/2005	SOMERVELL	144	727	41128
TX	SOMERVELL	TX4250068.17	MICHAEL L SIMMONS ET UX	6/8/2005	SOMERVELL			41900
TX	SOMERVELL	TX4250068.18	PRENTICE M MILAM JR ET UX	9/6/2005	SOMERVELL			41905
TX	SOMERVELL	TX4250068.19	S C FISHER JR ET UX	6/16/2006	SOMERVELL			44584
TX	SOMERVELL	TX4250068.20	MITCHELL L MILSON ET UX	6/1/2006	SOMERVELL			44623
TX	SOMERVELL	TX4250068.21	JEFFREY A GROVE ET UX	6/29/2006	SOMERVELL			44825
TX	SOMERVELL	TX4250068.24	DAVID RAY COFFIN	10/23/2006	SOMERVELL			46123
TX	SOMERVELL	TX4250068.25	DOROTHA MAY WEBB	11/7/2006	SOMERVELL			46121
TX	SOMERVELL	TX4250068.26	TOMMY MICHAEL UTLEY ET UX	10/23/2006	SOMERVELL			46122
TX	SOMERVELL	TX4250068.29	LYNN BRAXTON STEELMAN SR	3/16/2007	SOMERVELL			20071092
TX	SOMERVELL	TX4250068.30	WINDELL L DURANT	4/21/2005	SOMERVELL	142	455	40595
TX	SOMERVELL	TX4250068.31	GARY L VAUGHN ET UX	5/16/2005	SOMERVELL	143	42	40715
TX	SOMERVELL	TX4250068.32	J D ARMSTRONG JR	6/27/2006	SOMERVELL			44621
TX	SOMERVELL	TX4250068.33	WILLIAM JESSE PADON	6/15/2006	SOMERVELL			44622
TX	SOMERVELL	TX4250068.34	COLLEEN R HEDTKE	4/25/2005	SOMERVELL	142	466	40598
TX	SOMERVELL	TX4250068.35	ST TX MF-106859	9/19/2006	SOMERVELL			45807
TX	SOMERVELL	TX4250071.05	CHARLES WAYNE HOWELL SR ET UX	10/8/2011	SOMERVELL			20111862
TX	SOMERVELL	TX4250072.01	RONNIE M SHACKELFORD ET UX	8/28/2003	SOMERVELL	117	1	35659
TX	SOMERVELL	TX4250072.01	RONNIE M SHACKELFORD ET UX	8/28/2003
TX	SOMERVELL	TX4250072.05	WENDELL LEE STEPHENS ET UX	8/29/2011	SOMERVELL			20111727
TX	SOMERVELL	TX4250072.06	LOWELL DENE STEPHENS ET UX	9/6/2011	SOMERVELL			20111937
TX	SOMERVELL	TX4250074.01	EDWARD C HORNICK ET UX	9/4/2003	SOMERVELL	117	5	35660
TX	SOMERVELL	TX4250074.02	GLADYS M DAVIS	9/29/2005	SOMERVELL			42607
TX	SOMERVELL	TX4250074.03	SUSAN DOVE BONNEY	9/29/2005	SOMERVELL			42379
TX	SOMERVELL	TX4250074.04	FRANCES A B JENNER	9/29/2005	SOMERVELL			42606
TX	SOMERVELL	TX4250074.05	SAMUEL R BONNEY	8/25/2005	SOMERVELL			42284
TX	SOMERVELL	TX4250074.06	JOSEPH J BONNEY	8/25/2005	SOMERVELL			42428
TX	SOMERVELL	TX4250075.01	WILLIAM M HODGKINSON	9/11/2003	SOMERVELL	117	538	35779
TX	SOMERVELL	TX4250075.01	WILLIAM M HODGKINSON	9/11/2003
TX	SOMERVELL	TX4250075.01	WILLIAM M HODGKINSON	9/11/2003
TX	SOMERVELL	TX4250075.02	JENEANE HUFFMAN FLOYD	7/28/2011	SOMERVELL			20111536
TX	SOMERVELL	TX4250075.03	DAVID RANDOPH AND ROBIN THORMANN	12/1/2011	SOMERVELL			20120102
TX	SOMERVELL	TX4250075.04	LEATHA GAYLE MURPHY ET VIR	1/24/2012	SOMERVELL			20120272
TX	SOMERVELL	TX4250075.05	RAYMOND A THORMAN ET UX	1/24/2012	SOMERVELL			20120271
TX	SOMERVELL	TX4250075.06	TERRY N THORMAN ET UX	1/24/2012	SOMERVELL			20120508
TX	SOMERVELL	TX4250075.07	JANAN E JONES ET VIR	1/24/2012	SOMERVELL			20120506
TX	SOMERVELL	TX4250079.02	MERL W MITCHELL ET UX	10/8/2011	SOMERVELL			20111852
TX	SOMERVELL	TX4250079.03	JAMES DEWBERRY IND / IND EXEC	7/29/2014	SOMERVELL			20141679
TX	SOMERVELL	TX4250079.04	MARY E BOREN IND EXEC & TSTE	8/10/2014	SOMERVELL			20141667
TX	SOMERVELL	TX4250086.00	JOHN RANDALL BARNES	10/17/2003	SOMERVELL	119	298	36104
TX	SOMERVELL	TX4250086.00	JOHN RANDALL BARNES	10/17/2003
TX	SOMERVELL	TX4250086.00	JOHN RANDALL BARNES	10/17/2003
TX	SOMERVELL	TX4250092.01	HAROLD M MARKS ET AL	11/5/2003	SOMERVELL	119	843	36235
TX	SOMERVELL	TX4250092.01	HAROLD M MARKS ET AL	11/5/2003
TX	SOMERVELL	TX4250092.02	PATRICK WILIE	7/17/2007	SOMERVELL			20073015
TX	SOMERVELL	TX4250092.03	MICHAEL WILIE	7/17/2007	SOMERVELL			20072192
TX	SOMERVELL	TX4250097.01	JOHN CHARLES PARKER	8/15/2003	SOMERVELL	120	242	36304
TX	SOMERVELL	TX4250097.02	MARY RUTH PARKER	8/15/2003	SOMERVELL	120	245	36305
TX	HOOD AND SOMERVELL	TX4250099.00	ST TX M-103313	10/7/2003	SOMERVELL	119	823	36231
TX	HOOD AND SOMERVELL	TX4250099.00	ST TX M-103313	10/7/2003	HOOD	1969	424	19798
TX	BOSQUE AND SOMERVELL	TX4250103.00	ST TX M-103317	10/7/2003	BOSQUE	550	772	5572-03
TX	BOSQUE AND SOMERVELL	TX4250103.00	ST TX M-103317	10/7/2003	SOMERVELL	119	835	36233
TX	SOMERVELL	TX4250104.01	LAQUETTA OVERSTREET ETVIR	11/12/2003	SOMERVELL	120	660	36392
TX	SOMERVELL	TX4250104.02	CINDY G J BULL	6/20/2008	SOMERVELL			20081940
TX	SOMERVELL	TX4250108.01	NANCY JANE MOORE	11/5/2003	SOMERVELL	121	711	36575
TX	SOMERVELL	TX4250108.01	NANCY JANE MOORE	11/5/2003
TX	SOMERVELL	TX4250108.01	NANCY JANE MOORE	11/5/2003
TX	SOMERVELL	TX4250108.01	NANCY JANE MOORE	11/5/2003
TX	SOMERVELL	TX4250108.02	HENRY CLIFFORD WOMACK III	11/5/2003	SOMERVELL	121	707	36574
TX	SOMERVELL	TX4250108.02	HENRY CLIFFORD WOMACK III	11/5/2003
TX	SOMERVELL	TX4250108.02	HENRY CLIFFORD WOMACK III	11/5/2003
TX	SOMERVELL	TX4250108.02	HENRY CLIFFORD WOMACK III	11/5/2003
TX	SOMERVELL	TX4250108.02	HENRY CLIFFORD WOMACK III	11/5/2003
TX	SOMERVELL	TX4250110.01	LINDA R IVY ET VIR	10/15/2003	SOMERVELL	121	722	36579
TX	SOMERVELL	TX4250111.00	BILLY D STRICKLAND ET UX	11/21/2003	SOMERVELL	121	724	36580
TX	SOMERVELL	TX4250118.00	BILLY D STRICKLAND ET UX	1/9/2004	SOMERVELL	122	262	36689
TX	SOMERVELL	TX4250118.00	BILLY D STRICKLAND ET UX	1/9/2004
TX	SOMERVELL	TX4250120.00	BESSIE LEE ORR	1/22/2004	SOMERVELL	122	840	36818
TX	SOMERVELL	TX4250123.00	JACK M HART ET UX	1/29/2004	SOMERVELL	123	144	36861
TX	SOMERVELL	TX4250125.00	CLARA JEANNE HART	2/18/2004	SOMERVELL	123	491	36938
TX	SOMERVELL	TX4250129.02	WANDA S BLANKENSHIP	12/18/2014	SOMERVELL			20150467
TX	SOMERVELL	TX4250129.03	JERRY CHATWELL	12/15/2014	SOMERVELL			20150705
TX	SOMERVELL	TX4250129.04	JOE BRANDON KITCHENS	12/19/2014	SOMERVELL			20150706
TX	SOMERVELL	TX4250129.05	LOWELL HUTCHINS	12/18/2014	SOMERVELL			20150703
TX	SOMERVELL	TX4250129.06	SCOTT HUTCHENS	12/12/2014	SOMERVELL			20150707
TX	SOMERVELL	TX4250129.07	DEBRA RHOADS MILLER	12/15/2014	SOMERVELL			20150702
TX	SOMERVELL	TX4250129.08	BARBARA M KUNTZ	12/18/2015	SOMERVELL			20150704
TX	SOMERVELL	TX4250130.01	STEPHEN ERIC LEWELLEN	2/13/2004	SOMERVELL	124	28	37026
TX	SOMERVELL	TX4250130.02	MICHAEL KELLY LEWELLEN	2/13/2004	SOMERVELL	124	31	37027
TX	SOMERVELL	TX4250130.03	SAMMY & ANN MCCULLOUGH TR	2/13/2004	SOMERVELL	124	392	37109
TX	SOMERVELL	TX4250130.04	ALVIN G STEWART ET UX	2/19/2007	SOMERVELL		20070635
TX	SOMERVELL	TX4250130.04	ALVIN G STEWART ET UX	2/19/2007	HOOD	2278	488	3494
TX	SOMERVELL	TX4250133.00	GARRISON BARBARA NICKELL	3/12/2004	SOMERVELL	124	389	37108
TX	SOMERVELL	TX4250134.00	CEDAR RIDGE PARK INC	3/12/2004	SOMERVELL	124	387	37107
TX	SOMERVELL	TX4250135.00	PAT JACKSON FAUST	3/12/2004	SOMERVELL	124	385	37106
TX	SOMERVELL	TX4250141.00	W TX DIST-NAZARENE CHURCH	2/20/2004	SOMERVELL	124	714	37180
TX	SOMERVELL	TX4250142.04	RONNIE M SHACKELFORD ET UX	9/22/2003	SOMERVELL	117	560	35787
TX	SOMERVELL	TX4250142.04	RONNIE M SHACKELFORD ET UX	9/22/2003
TX	SOMERVELL	TX4250142.04	RONNIE M SHACKELFORD ET UX	9/22/2003
TX	SOMERVELL	TX4250146.00	PATMOS VISIONS L L C	4/8/2004	SOMERVELL	126	159	37393
TX	SOMERVELL	TX4250150.00	MICHAEL KELLEY LEWELLEN	5/3/2004	SOMERVELL	126	616	37501
TX	SOMERVELL	TX4250152.01	LIZA G FELDER TRUST ET AL	5/10/2004	SOMERVELL	127	804	37744
TX	SOMERVELL	TX4250152.01	LIZA G FELDER TRUST ET AL	5/10/2004
TX	SOMERVELL	TX4250152.01	LIZA G FELDER TRUST ET AL	5/10/2004
TX	SOMERVELL	TX4250152.01	LIZA G FELDER TRUST ET AL	5/10/2004
TX	SOMERVELL	TX4250152.01	LIZA G FELDER TRUST ET AL	5/10/2004
TX	SOMERVELL	TX4250152.02	DIANA GIBBS FELDER TRUST	5/10/2004	SOMERVELL	127	799	37743
TX	SOMERVELL	TX4250152.02	DIANA GIBBS FELDER TRUST	5/10/2004
TX	SOMERVELL	TX4250152.02	DIANA GIBBS FELDER TRUST	5/10/2004
TX	SOMERVELL	TX4250152.02	DIANA GIBBS FELDER TRUST	5/10/2004
TX	SOMERVELL	TX4250153.34	JUAN RODRIGUEZ ET UX	6/28/2011	SOMERVELL			20111378
TX	SOMERVELL	TX4250153.35	MIGUEL M BARRAZA ET UX	9/26/2011	SOMERVELL			20111789
TX	SOMERVELL	TX4250153.36	MICHAEL S CATES ET UX	9/26/2011	SOMERVELL			20111858
TX	SOMERVELL	TX4250156.02	LOUISE K PACE	7/20/2011	SOMERVELL			20111636
TX	SOMERVELL	TX4250159.01	ROLAND L STEGALL ET UX	6/3/2004	SOMERVELL	127	809	37745
TX	SOMERVELL	TX4250160.01	ROLAND LEE STEGALL ET UX	6/3/2004	SOMERVELL	129	371	38029
TX	SOMERVELL	TX4250161.00	GEORGE L GRAHAM ET UX	5/27/2004	SOMERVELL	128	355	37845
TX	SOMERVELL	TX4250165.17	PAUL ANDRE LAROCQUE	5/19/2011	SOMERVELL			20111125
TX	SOMERVELL	TX4250165.24	CELIA A SHACKELFORD ET VIR	5/28/2014	SOMERVELL			20141076
TX	SOMERVELL	TX4250165.25	WENDELL LEE STEPHENS ET UX	5/28/2014	SOMERVELL			20141074
TX	SOMERVELL	TX4250165.26	LYNETTE LORAINE ROGERS	6/12/2014	SOMERVELL			20141068
TX	SOMERVELL	TX4250165.27	LEWIS LYNLEY COWAN KEESE	6/12/2014	SOMERVELL			20141205
TX	SOMERVELL	TX4250165.28	BARRY CREED ET UX	9/25/2014	SOMERVELL			20141974
TX	SOMERVELL	TX4250165.29	WILLIAM C KIRKPATRICK ET UX	9/25/2014	SOMERVELL			20141976
TX	SOMERVELL	TX4250167.00	JESSE J LEE & LOUISE LEE	6/3/2004	SOMERVELL	128	322	37834
TX	SOMERVELL	TX4250171.00	LAVONNE N HOERNKE	6/3/2004	SOMERVELL	129	390	38034
TX	SOMERVELL	TX4250173.00	MARTHA FAYE OHLUND	7/28/2004	SOMERVELL	130	81	38175
TX	SOMERVELL	TX4250178.00	ALAN MARQUEZ ET UX	6/3/2004	SOMERVELL	130	615	38296
TX	SOMERVELL	TX4250203.00	ANITA MAE GOFF	9/7/2004	SOMERVELL	132	460	38620
TX	SOMERVELL	TX4250207.01	ANITA GOFF ETAL	9/7/2004	SOMERVELL	133	717	38885
TX	SOMERVELL	TX4250207.01	ANITA GOFF ETAL	9/7/2004
TX	SOMERVELL	TX4250207.01	ANITA GOFF ETAL	9/7/2004
TX	SOMERVELL	TX4250207.03	CHARLES W WEST	3/31/2008	SOMERVELL			20081062
TX	SOMERVELL	TX4250207.04	FLORINE WEST TIDWELL	3/31/2008	SOMERVELL			20081064
TX	SOMERVELL	TX4250207.05	LETA FAYE MOSES	3/31/2008	SOMERVELL			20081063
TX	SOMERVELL	TX4250215.00	DENNIS W REGER ET UX	8/19/2004	SOMERVELL	133	739	38893
TX	HOOD AND SOMERVELL	TX4250228.41	UNIMIN TEXAS COMPANY L P	6/25/2004	HOOD	2021	995	10552
TX	HOOD AND SOMERVELL	TX4250228.41	UNIMIN TEXAS COMPANY L P	6/25/2004
TX	HOOD AND SOMERVELL	TX4250228.41	UNIMIN TEXAS COMPANY L P	6/25/2004
TX	HOOD AND SOMERVELL	TX4250228.41	UNIMIN TEXAS COMPANY L P	6/25/2004
TX	HOOD AND SOMERVELL	TX4250228.41	UNIMIN TEXAS COMPANY L P	6/25/2004	SOMERVELL	128	590	37891
TX	HOOD AND SOMERVELL	TX4250228.41	UNIMIN TEXAS COMPANY L P	6/25/2004
TX	HOOD AND SOMERVELL	TX4250228.41	UNIMIN TEXAS COMPANY L P	6/25/2004
TX	HOOD AND SOMERVELL	TX4250228.41	UNIMIN TEXAS COMPANY L P	6/25/2004
TX	HOOD AND SOMERVELL	TX4250228.41	UNIMIN TEXAS COMPANY L P	6/25/2004
TX	SOMERVELL	TX4250231.01	J L WEEDON ET UX	10/26/2004	SOMERVELL	135	172	39149
TX	SOMERVELL	TX4250231.02	JACK W BRIDGES JR ET UX	10/26/2004	SOMERVELL	135	170	39148
TX	SOMERVELL	TX4250231.03	ROBERT B EVANS ET UX	10/26/2004	SOMERVELL	136	137	39371
TX	SOMERVELL	TX4250231.04	BOB J STEWART	10/26/2004	SOMERVELL	136	121	39364
TX	SOMERVELL	TX4250231.06	OAKDALE PARK INC	9/22/2004	SOMERVELL	133	525	38840
TX	SOMERVELL	TX4250242.07	MICHAEL P FRYE ET UX	9/10/2010	SOMERVELL			20101697
TX	SOMERVELL	TX4250242.07	MICHAEL P FRYE ET UX	9/10/2010
TX	SOMERVELL	TX4250242.08	JERRY R WATSON ET UX	10/15/2010	SOMERVELL			20101907
TX	SOMERVELL	TX4250242.09	WALL FAMILY TRUST A	11/20/2010	SOMERVELL			20102096
TX	SOMERVELL	TX4250242.11	ROBERT R RAITH ET UX	9/9/2011	SOMERVELL			20111792
TX	SOMERVELL	TX4250242.12	DARRELL G ATEN ET UX	9/9/2011	SOMERVELL			20111791
TX	SOMERVELL	TX4250243.01	ROBERT B EVANS ET UX	10/26/2004	SOMERVELL	136	113	39360
TX	SOMERVELL	TX4250243.02	BOB J STEWART	10/26/2004	SOMERVELL	136	119	39363
TX	SOMERVELL	TX4250243.03	J L WEEDON & ROXIE WEEDON	10/26/2004	SOMERVELL	136	117	39362
TX	SOMERVELL	TX4250243.04	JACK W BRIDGES ET UX	10/26/2004	SOMERVELL	136	115	39361
TX	SOMERVELL	TX4250243.05	DONALD J TALLMAN TRUSTEE	12/4/2005	SOMERVELL			42754
TX	SOMERVELL	TX4250243.06	ALFRED LEE CAGLE ET UX	4/30/2008	SOMERVELL			20081867
TX	SOMERVELL	TX4250243.07	FITE FAMILY TRUST	9/24/2007	SOMERVELL			20073079
TX	SOMERVELL	TX4250243.08	BLAINE WILSON BAXTER ET UX	7/18/2007	SOMERVELL			20072416
TX	SOMERVELL	TX4250243.09	THOMAS G MILBURN ET UX	8/7/2007	SOMERVELL			20072686
TX	SOMERVELL	TX4250245.00	INTERNATIONAL MISSIONS	12/6/2004	SOMERVELL	136	125	39366
TX	SOMERVELL	TX4250245.00	INTERNATIONAL MISSIONS	12/6/2004
TX	SOMERVELL	TX4250245.00	INTERNATIONAL MISSIONS	12/6/2004
TX	SOMERVELL	TX4250245.00	INTERNATIONAL MISSIONS	12/6/2004
TX	SOMERVELL	TX4250253.WD	BILLY T ROSS ET UX	3/30/2006	SOMERVELL			44505
TX	SOMERVELL	TX4250256.00	JOE BILL MARTIN ET UX	10/5/2009	SOMERVELL			20092141
TX	SOMERVELL	TX4250261.00	MIKE STICHT ET UX	1/26/2005	SOMERVELL	138	424	39826
TX	SOMERVELL	TX4250263.00	EUGENE F MOORE ET UX	2/2/2005	SOMERVELL	138	418	39824
TX	SOMERVELL	TX4250266.00	JEFF BOYD & TAMMY BOYD	2/2/2005	SOMERVELL	138	399	39817
TX	SOMERVELL	TX4250274.01	ZILPHA GAMBRELL	2/17/2005	SOMERVELL	139	327	39981
TX	SOMERVELL	TX4250274.01	ZILPHA GAMBRELL	2/17/2005
TX	SOMERVELL	TX4250274.01	ZILPHA GAMBRELL	2/17/2005
TX	SOMERVELL	TX4250274.04	KENNETH DWANE RUSSELL	5/12/2008	SOMERVELL			20081928
TX	SOMERVELL	TX4250274.05	ARTHUR CALVERT WILLIAMS	5/19/2008	SOMERVELL			20081927
TX	SOMERVELL	TX4250274.08	KATHY ANNE RUSSELL JAHNS	5/12/2008	SOMERVELL			20082115
TX	SOMERVELL	TX4250274.11	FRANK LEON WILLIAMS III	8/20/2008	SOMERVELL			20082928
TX	SOMERVELL	TX4250274.26	FRANK L WILLIAMS JR	3/28/2011	SOMERVELL			20110764
TX	SOMERVELL	TX4250274.27	SAMMIE E RUSSELL	3/28/2011	SOMERVELL			20110765
TX	SOMERVELL	TX4250277.00	LANCE CATHEY	2/14/2005	SOMERVELL	139	305	39974
TX	SOMERVELL	TX4250281.01	WELDON DON BAKER ET UX	2/23/2005	SOMERVELL	139	300	39972
TX	SOMERVELL	TX4250281.02	ROBERTS RANCH COMPANY	4/14/2005	SOMERVELL	143	9	40704
TX	SOMERVELL	TX4250281.03	INGRAM CONCRETE LLC	2/12/2008	SOMERVELL			20080711
TX	SOMERVELL	TX4250282.00	JOE G WHITWORTH ET UX	2/14/2005	SOMERVELL	139	317	39978
TX	SOMERVELL	TX4250282.00	JOE G WHITWORTH ET UX	2/14/2005
TX	SOMERVELL	TX4250282.00	JOE G WHITWORTH ET UX	2/14/2005
TX	SOMERVELL	TX4250291.00	PENNY SUE GRIFFIN PARKER	3/4/2005	SOMERVELL	140	479	40203
TX	SOMERVELL	TX4250291.00	PENNY SUE GRIFFIN PARKER	3/4/2005
TX	SOMERVELL	TX4250291.00	PENNY SUE GRIFFIN PARKER	3/4/2005
TX	SOMERVELL	TX4250312.WD	DOUGLAS B SWENDSEN / QRI	4/26/2005	SOMERVELL	142	822	40690
TX	SOMERVELL	TX4250330.01	BRIAN RHODES ET AL	3/17/2005	SOMERVELL	142	490	40607
TX	SOMERVELL	TX4250330.02	JACK WILLIAMS ET UX	4/28/2005	SOMERVELL	145	639	41268
TX	SOMERVELL	TX4250330.03	NORA J HARRISON	5/18/2005	SOMERVELL	144	213	41000
TX	SOMERVELL	TX4250330.05	REYNOLD SORGEE ET UX	5/24/2005	SOMERVELL	145	627	41264
TX	SOMERVELL	TX4250330.06	TOMMY C BENNETT ET AL	1/30/2007	SOMERVELL			20070695
TX	SOMERVELL	TX4250330.07	SHIRLEY L RUMFIELD HORTON	2/12/2007	SOMERVELL			20071402
TX	SOMERVELL	TX4250334.00	JESSE W BLAKLEY ET UX	5/12/2005	SOMERVELL	143	33	40712
TX	SOMERVELL	TX4250335.00	HAROLD LYNDON SULLIVAN	5/12/2005	SOMERVELL	143	36	40713
TX	SOMERVELL	TX4250336.00	RONALD DOYLE HANKINS	5/18/2005	SOMERVELL	143	39	40714
TX	SOMERVELL	TX4250339.00	CLOYCE G DAY	5/18/2005	SOMERVELL	143	54	40719
TX	SOMERVELL	TX4250341.00	SHELIA DIANE GOODWIN	5/9/2005	SOMERVELL	143	45	40716
TX	SOMERVELL	TX4250342.00	PHILEMON R STRAHM ET UX	5/12/2005	SOMERVELL	144	269	41019
TX	SOMERVELL	TX4250343.00	CHARLES R THOMAS SR ET UX	5/12/2005	SOMERVELL	144	266	41018
TX	SOMERVELL	TX4250346.07	MAURO D'ANGELO ET UX	6/24/2011	SOMERVELL			20111294
TX	SOMERVELL	TX4250346.08	JAMES R JONES	11/11/2011	SOMERVELL			20112139
TX	SOMERVELL	TX4250346.10	LAWRENCE HERBERT BARBERY ET UX	4/23/2012	SOMERVELL			20120798
TX	SOMERVELL	TX4250348.00	THOMAS L FISHER ET UX	5/12/2005	SOMERVELL	144	192	40993
TX	SOMERVELL	TX4250349.00	WILLIAM D BAZE ET UX	5/12/2005	SOMERVELL	144	195	40994
TX	SOMERVELL	TX4250350.00	HAROLD W HAMMOND ET UX	5/12/2005	SOMERVELL	144	198	40995
TX	SOMERVELL	TX4250351.00	GARY J JORDAN ET UX	5/18/2005	SOMERVELL	144	203	40997
TX	SOMERVELL	TX4250352.00	MICHAEL LEGOFFE ET UX	5/25/2005	SOMERVELL	144	207	40998
TX	SOMERVELL	TX4250353.00	GARY D LYTLE ET UX	5/12/2005	SOMERVELL	144	210	40999
TX	SOMERVELL	TX4250357.00	BRIAN S STATLER ET UX	5/12/2005	SOMERVELL	144	730	41129
TX	SOMERVELL	TX4250359.00	DARLA JONITA ANDERSON	5/12/2005	SOMERVELL	144	710	41122
TX	SOMERVELL	TX4250362.00	ARCH WILLIAM GIBSON ET UX	1/26/2005	SOMERVELL	144	715	41124
TX	SOMERVELL	TX4250363.03	JAMES SEIDENGLANZ ET UX	8/25/2014	SOMERVELL			20141658
TX	SOMERVELL	TX4250364.00	KENNETH WADE OGDEN ET UX	5/12/2005	SOMERVELL	144	722	41126
TX	SOMERVELL	TX4250368.00	JACK M KELLY & LINDA KELLY	5/12/2005	SOMERVELL	145	621	41262
TX	SOMERVELL	TX4250369.00	LOUIS COCITA ET UX	6/7/2005	SOMERVELL	145	618	41261
TX	SOMERVELL	TX4250370.00	RIO VISTA PROPERTY ASSOC	5/12/2005	SOMERVELL	145	624	41263
TX	SOMERVELL	TX4250372.00	STARLING G WHALEN ET UX	5/18/2005	SOMERVELL	145	605	41256
TX	SOMERVELL	TX4250377.00	MARK SHRYACK ET UX	5/25/2005	SOMERVELL	145	644	41269
TX	SOMERVELL	TX4250387.00	STEVEN DEREK MIMS ET UX	5/12/2005	SOMERVELL	147	620	41628
TX	SOMERVELL	TX4250388.99	HUNTER / CLEVELAND / QRI	8/16/2005	SOMERVELL			20071094
TX	SOMERVELL	TX4250390.00	CHARLES E FULLER ET UX	5/31/2005	SOMERVELL	147	632	41630
TX	SOMERVELL	TX4250393.00	BILLY P BAKER ET UX	5/25/2005	SOMERVELL	147	598	41620
TX	SOMERVELL	TX4250394.00	MARY LOU DOSHIER	7/20/2005	SOMERVELL	147	595	41619
TX	SOMERVELL	TX4250400.00	PATRICK T ENGLISH ET UX	5/18/2005	SOMERVELL			41915
TX	SOMERVELL	TX4250401.00	BOBBIE KELLER	6/2/2005	SOMERVELL			41916
TX	SOMERVELL	TX4250401.00	BOBBIE KELLER	6/2/2005
TX	SOMERVELL	TX4250403.00	AARON D SMITH ET UX	8/12/2005	SOMERVELL			41901
TX	SOMERVELL	TX4250409.00	GARY LYNN ADAMS ET UX	5/12/2005	SOMERVELL			41897
TX	SOMERVELL	TX4250411.00	FRANCES K CARPENTER	8/16/2005	SOMERVELL			41899
TX	SOMERVELL	TX4250415.13	CLAY EDWARD GARLAND	9/26/2011	SOMERVELL			20112010
TX	SOMERVELL	TX4250415.14	THEODORE HUFFMAN GARLAND	9/26/2011	SOMERVELL			20112009
TX	SOMERVELL	TX4250415.15	BETTY LOUISE GARLAND HARKINS	9/26/2011	SOMERVELL			20112006
TX	SOMERVELL	TX4250415.16	ESTELLA JANE GARLAND GREENWAY	9/26/2011	SOMERVELL			20112007
TX	SOMERVELL	TX4250415.17	DAVID CLAY PAYNE	9/26/2011	SOMERVELL			20112008
TX	SOMERVELL	TX4250415.18	JANE HUFFMAN GRACE FAMILY TRUST	9/26/2011	SOMERVELL			20112145
TX	SOMERVELL	TX4250424.01	NICKEY HULSEY ET UX	8/18/2005	SOMERVELL			42068
TX	SOMERVELL	TX4250424.02	VIRGIL D WILLEY	7/18/2008	SOMERVELL			20082358
TX	SOMERVELL	TX4250424.03	SHIRLEY W BODOH	7/18/2008	SOMERVELL			20082359
TX	SOMERVELL	TX4250424.04	LAVERNE W EMERY	7/21/2008	SOMERVELL			20082360
TX	SOMERVELL	TX4250424.05	TERESA WILLEY THOMAS ETVIR	11/4/2009	SOMERVELL			20092272
TX	SOMERVELL	TX4250434.00	JOHN H HEINFELD ET UX	9/28/2005	SOMERVELL			42287
TX	SOMERVELL	TX4250434.00	JOHN H HEINFELD ET UX	9/28/2005
TX	SOMERVELL	TX4250434.00	JOHN H HEINFELD ET UX	9/28/2005
TX	SOMERVELL	TX4250438.00	JOS OUTEN ET UX IND & TR	5/12/2005	SOMERVELL			42368
TX	SOMERVELL	TX4250439.00	DONALD J TALLMAN TRUSTEE	10/11/2005	SOMERVELL			42768
TX	SOMERVELL	TX4250441.00	KEITH E JOHNSON ET UX	9/15/2005	SOMERVELL			42292
TX	SOMERVELL	TX4250441.00	KEITH E JOHNSON ET UX	9/15/2005
TX	SOMERVELL	TX4250441.00	KEITH E JOHNSON ET UX	9/15/2005
TX	SOMERVELL	TX4250442.00	KERRY T HANCOCK ET UX	8/25/2005	SOMERVELL			42285
TX	SOMERVELL	TX4250443.04	HAPPY HILL FARM	6/17/2014	SOMERVELL			20141073
TX	SOMERVELL	TX4250443.05	ROBERT M WILSON ET UX	6/25/2014	SOMERVELL			20141307
TX	SOMERVELL	TX4250443.06	WILLIAM CLARENCE MOORE	8/22/2014	SOMERVELL			20141659
TX	SOMERVELL	TX4250443.07	MARSHA RAE MOORE	8/22/2014	SOMERVELL			20141802
TX	SOMERVELL	TX4250446.00	SABRA MERRIMAN GENT	9/27/2005	SOMERVELL			42424
TX	SOMERVELL	TX4250449.00	DEWEY MILLER / VLB	10/1/2005	SOMERVELL			42594
TX	SOMERVELL	TX4250450.00	DANIEL B HARTMAN ET UX	8/25/2005	SOMERVELL			42416
TX	SOMERVELL	TX4250451.00	JIMMY DON ROBERSON ET UX	8/25/2005	SOMERVELL			42372
TX	SOMERVELL	TX4250452.00	BARBARA NAN DEAREN	9/26/2005	SOMERVELL			42373
TX	SOMERVELL	TX4250454.00	DEWEY MILLER	10/1/2005	SOMERVELL			42423
TX	SOMERVELL	TX4250457.00	CURTIS MORGAN ET UX	11/1/2005	SOMERVELL			42769
TX	SOMERVELL	TX4250464.00	CARL T BECK	9/13/2005	SOMERVELL			42591
TX	SOMERVELL	TX4250477.00	JOSE A RINCON ET UX / VLB	8/25/2005	SOMERVELL			43487
TX	SOMERVELL	TX4250480.02	MICHAEL A STEPHENSON ET UX	5/5/2011	SOMERVELL			20111052
TX	SOMERVELL	TX4250482.02	DONNA J SCHOTT	4/27/2011	SOMERVELL			20110958
TX	SOMERVELL	TX4250484.02	ELDON L HOOLEY ET UX	4/27/2011	SOMERVELL			20110957
TX	SOMERVELL	TX4250500.02	ALICIA DUPLAN ET VIR	10/1/2008	SOMERVELL			20090171
TX	SOMERVELL	TX4250500.04	RONALD CLYDE SEXTON ET UX	8/26/2003	SOMERVELL	117	34	35669
TX	SOMERVELL	TX4250500.04	RONALD CLYDE SEXTON ET UX	8/26/2003
TX	SOMERVELL	TX4250514.00	NEAL BIELER ET UX	8/25/2005	SOMERVELL			43039
TX	SOMERVELL	TX4250518.00	JOHN A GRAVES ET UX	8/17/2004	SOMERVELL	144	429	41062
TX	SOMERVELL	TX4250524.00	DWAIN SANDLIN ET AL	6/22/2004	SOMERVELL	128	317	37833
TX	SOMERVELL	TX4250528.00	DOROTHIE I J SPARKS ET AL	8/4/2004	SOMERVELL	130	214	38208
TX	SOMERVELL	TX4250529.00	WANDA CHEEK SPARKS	8/4/2004	SOMERVELL	130	209	38207
TX	SOMERVELL	TX4250552.02	KIMBERLY ANNE YENNERELL	7/12/2011	SOMERVELL			20111543
TX	SOMERVELL	TX4250554.02	JOHN REED	9/9/2011	SOMERVELL			20111796
TX	SOMERVELL	TX4250554.03	STEPHEN C SIMS	9/9/2011	SOMERVELL			20111795
TX	SOMERVELL	TX4250561.00	PATRICK W POWELL ET UX	1/11/2006	SOMERVELL			43499
TX	SOMERVELL	TX4250578.00	STUART M CAMP	2/23/2006	SOMERVELL			43685
TX	SOMERVELL	TX4250593.00	SARAH DUPUIS	1/11/2006	SOMERVELL			43989
TX	SOMERVELL	TX4250594.00	THE RILEY FAMILY TRUST	1/10/2006	SOMERVELL			44287
TX	SOMERVELL	TX4250596.02	JAMES M MALONE	9/1/2011	SOMERVELL			20111721
TX	SOMERVELL	TX4250597.00	MELVILLE W FORD ET UX	5/1/2006	SOMERVELL			44274
TX	SOMERVELL	TX4250603.01	RITA HARRIS STAPP	4/10/2006	SOMERVELL			44276
TX	SOMERVELL	TX4250606.MD	ELEANOR D OGLESBY / QRI	3/30/2006	SOMERVELL			44502
TX	SOMERVELL	TX4250608.MD	JAMES N DOUGLAS JR / QRI	3/30/2006	SOMERVELL			45485
TX	SOMERVELL	TX4250609.99	L SELLERS FULENWIDER EST / QRI	3/30/2006	SOMERVELL			44690
TX	SOMERVELL	TX4250610.99	ROBERT STAMEY HAUSS EST / QRI	3/30/2006	SOMERVELL			44689
TX	SOMERVELL	TX4250611.99	ROBERT H RHYNE ET UX / QRI	3/30/2006	SOMERVELL			44513
TX	SOMERVELL	TX4250612.MD	MELISSA EDENTON GERMAN / QRI	3/30/2006	SOMERVELL			44504
TX	SOMERVELL	TX4250613.MD	MIRIAM T CHURCHWELL / QRI	3/30/2006	SOMERVELL			44503
TX	SOMERVELL	TX4250644.02	SAM A MASSEY ET UX	8/15/2011	SOMERVELL			20111533
TX	SOMERVELL	TX4250645.04	INOCENCIA ALVAREZ	9/21/2011	SOMERVELL			20111790
TX	SOMERVELL	TX4250647.00	JAMES DEAN DUGGER ET UX	8/23/2006	SOMERVELL			45335
TX	SOMERVELL	TX4250654.WD	CHARLOTTE O TAYLOR / QRI	3/30/2006	SOMERVELL			45486
TX	SOMERVELL	TX4250655.02	SYBIL PARSLEY	8/10/2011	SOMERVELL			20111535
TX	SOMERVELL	TX4250657.00	JASON MORDEN ET UX	9/15/2006	SOMERVELL			45738
TX	SOMERVELL	TX4250658.00	JOHN G TUCKER ET UX	9/16/2006	SOMERVELL			45739
TX	SOMERVELL	TX4250661.01	JUAN RODRIGUEZ ET UX	9/26/2006	SOMERVELL			46006
TX	SOMERVELL	TX4250665.00	LARRY J MORDEN ET UX	9/18/2006	SOMERVELL			45735
TX	SOMERVELL	TX4250669.00	KEVIN E KELLER ET UX	9/1/2006	SOMERVELL			45998
TX	SOMERVELL	TX4250672.02	MIGUEL H LARA ET UX	11/4/2011	SOMERVELL			20112073
TX	SOMERVELL	TX4250680.00	WALTER B STEWART III ET UX	11/2/2006	SOMERVELL			46118
TX	SOMERVELL	TX4250710.01	JAMES BARNARD	11/22/2006	SOMERVELL			46241
TX	SOMERVELL	TX4250710.02	WM R KELLY AIF MARIE KELLY	11/22/2006	SOMERVELL			46170
TX	SOMERVELL	TX4250710.03	EDDIE LALONE	11/28/2006	SOMERVELL			46172
TX	SOMERVELL	TX4250710.04	GEORGIA BROWN KELLY	11/28/2006	SOMERVELL			20070036
TX	SOMERVELL	TX4250710.05	MIKE KELLY	12/13/2006	SOMERVELL			46242
TX	SOMERVELL	TX4250710.06	SHANNON KELLY	12/13/2006	SOMERVELL			46243
TX	SOMERVELL	TX4250710.07	ROBIN KELLY ALSTON	12/13/2006	SOMERVELL			46244
TX	SOMERVELL	TX4250710.08	WAYNE KELLY	11/22/2006	SOMERVELL			20070007
TX	SOMERVELL	TX4250710.09	PEGGY A KELLY MCVEAN	11/22/2006	SOMERVELL			46247
TX	SOMERVELL	TX4250710.10	SANDRA JO KELLY BECK	12/13/2006	SOMERVELL			46248
TX	SOMERVELL	TX4250710.11	DAVID WADE KELLY	12/13/2006	SOMERVELL			46249
TX	SOMERVELL	TX4250710.12	LINDA G KELLY STREUN	12/13/2006	SOMERVELL			46246
TX	SOMERVELL	TX4250710.13	LARRY KELLY	12/13/2006	SOMERVELL			46245
TX	SOMERVELL	TX4250710.14	BONNYLOU YOLANDA COLE	11/22/2006	SOMERVELL			20070009
TX	SOMERVELL	TX4250710.15	JASON JONES	11/22/2006	SOMERVELL			20070011
TX	SOMERVELL	TX4250710.16	PATRICIA HALL	11/22/2006	SOMERVELL			20070006
TX	SOMERVELL	TX4250710.17	LAURA JONELL CROSS	11/22/2006	SOMERVELL			20070008
TX	SOMERVELL	TX4250710.18	BRENDA J BOHN	11/22/2006	SOMERVELL			20070010
TX	SOMERVELL	TX4250710.19	LOURDES A KELLY SALISBURY	11/28/2006	SOMERVELL			46171
TX	SOMERVELL	TX4250726.00	LARRY PEURIFOY ET UX	2/14/2007	SOMERVELL			20070687
TX	SOMERVELL	TX4250726.00	LARRY PEURIFOY ET UX	2/14/2007
TX	SOMERVELL	TX4250727.00	RODRIGO SANCHEZ ET UX	2/16/2007	SOMERVELL			20070692
TX	SOMERVELL	TX4250727.00	RODRIGO SANCHEZ ET UX	2/16/2007
TX	SOMERVELL	TX4250727.00	RODRIGO SANCHEZ ET UX	2/16/2007
TX	SOMERVELL	TX4250736.00	ORLAN H PARISH	2/16/2007	SOMERVELL			20070693
TX	SOMERVELL	TX4250736.00	ORLAN H PARISH	2/16/2007
TX	SOMERVELL	TX4250736.00	ORLAN H PARISH	2/16/2007
TX	SOMERVELL	TX4250739.00	JEFFREY B SLATON ET UX	2/22/2007	SOMERVELL			20070836
TX	SOMERVELL	TX4250739.00	JEFFREY B SLATON ET UX	2/22/2007
TX	SOMERVELL	TX4250740.10	SAN SABA ROYALTY COMPANY	3/15/2012	SOMERVELL			20120596
TX	SOMERVELL	TX4250755.00	MARY L GAINES LINDSAY	4/19/2007	SOMERVELL			20071694
TX	SOMERVELL	TX4250764.99	MODTECH HOLDING / MAGNITUDE	5/1/2007	SOMERVELL			20071414
TX	SOMERVELL	TX4250766.00	ARTHUR LANE ET UX	6/4/2007	SOMERVELL			20072023
TX	SOMERVELL	TX4250768.99	BERTRAND TAYLOR	5/1/2007	SOMERVELL			20071413
TX	SOMERVELL	TX4250776.18	JOHN BOSWELL ET UX	6/23/2011	SOMERVELL			20111376
TX	SOMERVELL	TX4250781.99	ESTATE OF MARY SHIELDS	3/30/2006	SOMERVELL			44506
TX	SOMERVELL	TX4250784.00	GEORGIA MAE RHODES	8/20/2007	SOMERVELL			20072848
TX	SOMERVELL	TX4250784.00	GEORGIA MAE RHODES	8/20/2007
TX	SOMERVELL	TX4250785.99	BJKS PROPERTIES LTD	6/22/2007	SOMERVELL			20071926
TX	SOMERVELL	TX4250787.00	ST TX M-108336	10/16/2007	SOMERVELL			20073303
TX	SOMERVELL	TX4250792.00	GEORGES CREEK CEMETERY AS	11/14/2007	SOMERVELL			20073390
TX	SOMERVELL	TX4250810.14	MADELEINE SUE (PAT) WINDHAM	6/28/2014	SOMERVELL			20141204
TX	SOMERVELL	TX4250810.15	DENNIS BOLTON	7/3/2014	SOMERVELL			20141212
TX	SOMERVELL	TX4250810.16	RICHARD R MORRISON ET UX	7/18/2014	SOMERVELL			20141313
TX	SOMERVELL	TX4250810.17	HAYLEY E DARNELL ET VIR	7/11/2014	SOMERVELL			20141676
TX	SOMERVELL	TX4250810.18	ALEXANDER PROPERTY INTERESTS LLC	7/31/2014	SOMERVELL			20141970
TX	SOMERVELL	TX4250810.19	MARSHA C BAKER	10/14/2014	SOMERVELL			20150125
TX	SOMERVELL	TX4250811.01	CONNIE D CARPENTER	3/24/2008	SOMERVELL			20081051
TX	SOMERVELL	TX4250811.02	DAVID L CARPENTER	3/24/2008	SOMERVELL			20081076
TX	SOMERVELL	TX4250812.05	ROBERT G FRYE ET UX	7/16/2014	SOMERVELL			20141309
TX	SOMERVELL	TX4250813.00	LLOYD M WIRT JR	4/7/2008	SOMERVELL			20081124
TX	SOMERVELL	TX4250814.01	CHARLES WIRT TRUST	4/7/2008	SOMERVELL			20081123
TX	SOMERVELL	TX4250814.02	LLOYD M WIRT JR ET UX	4/7/2008	SOMERVELL			20081125
TX	SOMERVELL	TX4250816.02	ALBERT T HAMMON ET UX	7/3/2014	SOMERVELL			20141210
TX	SOMERVELL	TX4250817.00	ST TX 109100 / CHEYENNE HILLS	3/31/2008	SOMERVELL			20081163
TX	SOMERVELL	TX4250820.01	JOHN C SULLIVAN ET UX	3/3/2008	SOMERVELL			20081930
TX	SOMERVELL	TX4250820.01	JOHN C SULLIVAN ET UX	3/3/2008
TX	SOMERVELL	TX4250820.02	JENNIFER L SULLIVAN	4/9/2008	SOMERVELL			20081936
TX	SOMERVELL	TX4250820.02	JENNIFER L SULLIVAN	4/9/2008
TX	SOMERVELL	TX4250820.02	JENNIFER L SULLIVAN	4/9/2008
TX	SOMERVELL	TX4250841.01	BILLY C MILLER ET UX	6/25/2008	SOMERVELL			20082114
TX	SOMERVELL	TX4250841.02	CHARLES PRICE CONNALLY	6/25/2008	SOMERVELL			20082049
TX	SOMERVELL	TX4250841.03	MARY CONNALLY LINDSAY	6/25/2008	SOMERVELL			20082113
TX	SOMERVELL	TX4250841.04	GUY SPENCER HAMMONS	6/25/2008	SOMERVELL			20082184
TX	SOMERVELL	TX4250841.05	GAYLA ANN HAMMONS	6/25/2008	SOMERVELL			20082183
TX	SOMERVELL	TX4250841.06	FAY G BASS	6/25/2008	SOMERVELL			20082055
TX	SOMERVELL	TX4250841.07	CHARLES ROBERT CONNALLY	6/25/2008	SOMERVELL			20082185
TX	SOMERVELL	TX4250843.00	ST TX 109124	7/1/2008	SOMERVELL			20082054
TX	SOMERVELL	TX4250848.00	RILEY F GIBBS	6/2/2004	SOMERVELL	129	110	37963
TX	SOMERVELL	TX4250856.00	RONALD C CRAIG ET UX	2/12/2008	SOMERVELL			20082307
TX	SOMERVELL	TX4250860.00	CHEYENNE HILLS/GLEN ROSE	7/21/2008	SOMERVELL			20082308
TX	SOMERVELL	TX4250864.00	ST TX M-109206	7/1/2008	SOMERVELL			20082301
TX	SOMERVELL	TX4250865.00	ST TX M-109288	7/22/2008
TX	SOMERVELL	TX4250866.00	ST TX M-109289	7/22/2008
TX	SOMERVELL	TX4250876.01	THEDA M P ROARK ET VIR	10/14/2008	SOMERVELL			20083111
TX	SOMERVELL	TX4250876.01	THEDA M P ROARK ET VIR	10/14/2008
TX	SOMERVELL	TX4250881.00	GEORGES CREEK BPST CHURCH	10/11/2008	SOMERVELL			20083105
TX	SOMERVELL	TX4250883.01	TERRY WAYNE GOSDIN ET UX	10/6/2008	SOMERVELL			20083363
TX	SOMERVELL	TX4250883.01	TERRY WAYNE GOSDIN ET UX	10/6/2008
TX	SOMERVELL	TX4250887.99	BANK OF AMERICA	3/12/2008	SOMERVELL			20080772
TX	HOOD AND SOMERVELL	TX4250892.00	ST TX M-108269	9/18/2007
TX	SOMERVELL	TX4250897.02	UNCLE GEORGE'S SPORTING GOODS	7/31/2014	SOMERVELL			20141527
TX	SOMERVELL	TX4250898.00	TISSERAND & COX LIV TRUSTS	1/13/2009	SOMERVELL			20090397
TX	SOMERVELL	TX4250900.00	ST TX M-109905	12/16/2008
TX	SOMERVELL	TX4250901.00	ST TX M-109903	12/16/2008
TX	SOMERVELL	TX4250902.00	ST TX M-109904	12/16/2008
TX	SOMERVELL	TX4250905.01	B&B MIETH FAMILY LTD PART	3/30/2009	SOMERVELL			20090673
TX	SOMERVELL	TX4250906.00	BEN MIETH JR CHAR UNITRUST	3/30/2009	SOMERVELL			20090672
TX	SOMERVELL	TX4250908.04	HENRY CLIFFORD WOMACK III	4/11/2012	SOMERVELL			20120632
TX	SOMERVELL	TX4250908.05	DONALD NEIL WOMACK	4/11/2012	SOMERVELL			20120715
TX	SOMERVELL	TX4250908.06	NANCY JANE MOORE	4/11/2012	SOMERVELL			20120716
TX	SOMERVELL	TX4250913.00	LESLIE N ANDERSON ET UX	4/24/2009	SOMERVELL			20090860
TX	SOMERVELL	TX4250931.00	DAVID E MIMMS SR ET UX	8/11/2009	SOMERVELL			20091735
TX	SOMERVELL	TX4250952.01	BETSILL ENERGY LLC	10/28/2009	SOMERVELL			20092140
TX	SOMERVELL	TX4250952.01	BETSILL ENERGY LLC	10/28/2009
TX	SOMERVELL	TX4250952.01	BETSILL ENERGY LLC	10/28/2009
TX	SOMERVELL	TX4250952.02	SCOTT CHAFFIN ET UX	11/4/2009	SOMERVELL			20092269
TX	SOMERVELL	TX4250952.02	SCOTT CHAFFIN ET UX	11/4/2009
TX	SOMERVELL	TX4250953.00	ST TX MF-110529	12/1/2009	SOMERVELL			20092322
TX	SOMERVELL	TX4250955.00	KENNETH E BARNARD ET UX	11/11/2009	SOMERVELL			20092271
TX	SOMERVELL	TX4250973.00	J L HERRING ET UX	6/30/2010	SOMERVELL			20101273
TX	SOMERVELL	TX4250980.01	JAMES W GOSDIN ET UX	8/27/2010	SOMERVELL			20101632
TX	SOMERVELL	TX4250980.02	HENRY C WOMACK III	11/14/2010	SOMERVELL			20101993
TX	SOMERVELL	TX4250980.03	DONALD NEIL WOMACK	11/14/2010	SOMERVELL			20101994
TX	SOMERVELL	TX4250980.04	NANCY JANE WOMACK MOORE	11/14/2010	SOMERVELL			20102055
TX	SOMERVELL	TX4250985.01	RONDAL L BOREN	10/14/2010	SOMERVELL			20101901
TX	SOMERVELL	TX4250985.02	HAZEL WOODARD	1/18/2011	SOMERVELL			20110321
TX	SOMERVELL	TX4250985.03	LESLIE G WOODARD	1/18/2011	SOMERVELL			20110320
TX	SOMERVELL	TX4250985.04	CAROLYN BOWLING ET VIR	1/18/2011	SOMERVELL			20110319
TX	SOMERVELL	TX4250985.05	WESLEY D WOODARD	1/18/2011	SOMERVELL			20110322
TX	SOMERVELL	TX4250985.06	CHARLES M WOODARD	1/20/2011	SOMERVELL			20110478
TX	SOMERVELL	TX4250985.07	BENNY HAROLD WOODARD JR	1/20/2011	SOMERVELL			20110477
TX	SOMERVELL	TX4250985.08	DEBRA A WOODARD	1/18/2011	SOMERVELL			20110317
TX	SOMERVELL	TX4250985.09	JOAN SEILER	1/18/2011	SOMERVELL			20110316
TX	SOMERVELL	TX4250985.10	TERRY E RIVES	1/24/2011	SOMERVELL			20110318
TX	SOMERVELL	TX4250985.11	WENDY R CANARD	1/20/2011	SOMERVELL			20110480
TX	SOMERVELL	TX4250985.12	PAULINE NEWMAN	1/31/2011	SOMERVELL			20110481
TX	SOMERVELL	TX4250985.13	WAYLAND RUSSELL WOODARD	1/20/2011	SOMERVELL			20110479
TX	SOMERVELL	TX4250985.14	ROY D WOODARD ET UX	1/18/2011	SOMERVELL			20110475
TX	SOMERVELL	TX4250985.15	TAMMY S MASK	1/20/2011	SOMERVELL			20110476
TX	SOMERVELL	TX4250985.16	LARRY D GILLEY	1/18/2011	SOMERVELL			20110482
TX	SOMERVELL	TX4250985.17	OLIVER EUGENE GILLEY	1/18/2011	SOMERVELL			20110483
TX	SOMERVELL	TX4250985.18	MELLEA LYNN MCLAUGHLIN	1/20/2011	SOMERVELL			20110596
TX	SOMERVELL	TX4250985.19	MARY J WOODARD	2/28/2011	SOMERVELL			20110597
TX	SOMERVELL	TX4250985.20	CAROLYN GILEY SCHROEDER ET VIR	1/18/2011	SOMERVELL			20110665
TX	SOMERVELL	TX4250985.21	RANDY R WOODARD ET UX	3/8/2011	SOMERVELL			20110662
TX	SOMERVELL	TX4250987.00	CURTIS RAY ROSE ET UX	11/30/2010	SOMERVELL			20102098
TX	SOMERVELL	TX4250989.00	PHILLIP VOSS ET UX	11/30/2010	SOMERVELL			20102136
TX	SOMERVELL	TX4250990.01	B LANCE MOODY	12/22/2010	SOMERVELL			20110095
TX	SOMERVELL	TX4250990.02	HERMAN D BATY	12/22/2010	SOMERVELL			20110094
TX	SOMERVELL	TX4250990.03	ROGER HAMILTON SMITH ET UX	12/14/2010	SOMERVELL			20110093
TX	SOMERVELL	TX4250990.04	CLODELL DAVIS	1/6/2011	SOMERVELL			20110136
TX	SOMERVELL	TX4250990.05	R D FORD	1/6/2011	SOMERVELL			20110135
TX	SOMERVELL	TX4250990.06	HIRSE L GRAHAM	1/6/2011	SOMERVELL			20110139
TX	SOMERVELL	TX4250990.07	BARBARA ELOISE EVANS	1/12/2011	SOMERVELL			20110138
TX	SOMERVELL	TX4250990.08	BILLIE J LITTLE	1/6/2011	SOMERVELL			20110137
TX	SOMERVELL	TX4250990.09	DOYLE GRAHAM	1/6/2011	SOMERVELL			20110223
TX	SOMERVELL	TX4250990.10	LEVONA GRAHAM MACON	1/6/2011	SOMERVELL			20110218
TX	SOMERVELL	TX4250990.11	STAN MARTIN ET UX	1/6/2011	SOMERVELL			20110219
TX	SOMERVELL	TX4250990.12	JOYCE CAROL GRAHAM MCCULLAR	1/6/2011	SOMERVELL			20110220
TX	SOMERVELL	TX4250990.13	DOROTHY MUSE COX	1/6/2011	SOMERVELL			20110221
TX	SOMERVELL	TX4250990.14	WAYNE C GRAHAM	1/10/2011	SOMERVELL			20110222
TX	SOMERVELL	TX4250990.15	MILDRED MORRIS	1/6/2011	SOMERVELL			20110224
TX	SOMERVELL	TX4250990.16	VIVIA E DITMORE ET VIR	1/12/2011	SOMERVELL			20110225
TX	SOMERVELL	TX4250990.17	KYLE MARTIN ET UX	1/6/2011	SOMERVELL			20110328
TX	SOMERVELL	TX4250990.18	ARMENTHA C MARTIN	1/6/2011	SOMERVELL			20110327
TX	SOMERVELL	TX4250990.19	STACEY MUNSELL ET VIR	1/6/2011	SOMERVELL			20110326
TX	SOMERVELL	TX4250990.20	JOSEPH RANDALL MARTIN JR ET UX	1/6/2011	SOMERVELL			20110329
TX	SOMERVELL	TX4250990.21	WALTER LEONARD HOOD	1/6/2011	SOMERVELL			20110330
TX	SOMERVELL	TX4250990.22	CAROL ANN GRAHAM	1/12/2011	SOMERVELL			20110331
TX	SOMERVELL	TX4250990.23	KENNETH LITTLE	1/10/2011	SOMERVELL			20110332
TX	SOMERVELL	TX4250990.24	WILLENE D KEENUM	1/20/2011	SOMERVELL			20110333
TX	SOMERVELL	TX4250990.25	GLADYS MAYHAR	1/10/2011	SOMERVELL			20110334
TX	SOMERVELL	TX4250990.26	GARY W BLACKWELL	1/25/2011	SOMERVELL			20110324
TX	SOMERVELL	TX4250990.27	PAULINE MEARS	1/25/2011	SOMERVELL			20110325
TX	SOMERVELL	TX4250990.28	WILLIAM HAWKINS ET UX	1/18/2011	SOMERVELL			20110335
TX	SOMERVELL	TX4250990.29	HENRY W BLACKWELL ET UX	1/25/2011	SOMERVELL			20110323
TX	SOMERVELL	TX4250990.30	BETTY MARS ET VIR	1/17/2011	SOMERVELL			20110484
TX	SOMERVELL	TX4250990.31	GEORGE KEENUM	1/12/2011	SOMERVELL			20110464
TX	SOMERVELL	TX4250990.32	MARK LITTLE	2/10/2011	SOMERVELL			20110468
TX	SOMERVELL	TX4250990.33	BILLIE KEENUM ROBERSON	2/17/2011	SOMERVELL			20110487
TX	SOMERVELL	TX4250990.34	CLOYCE LITTLE	2/20/2011	SOMERVELL			20110485
TX	SOMERVELL	TX4250990.35	SONDRA M HEATON	2/17/2011	SOMERVELL			20110486
TX	SOMERVELL	TX4250990.36	RUTH K VAN NOSTRAND ET VIR	2/10/2011	SOMERVELL			20110490
TX	SOMERVELL	TX4250990.37	JOYCE KELSO LEE AKA WILLIS	2/7/2011	SOMERVELL			20110488
TX	SOMERVELL	TX4250990.38	VICKI OAKES	2/10/2011	SOMERVELL			20110489
TX	SOMERVELL	TX4250990.39	NAN CARPENTER	1/12/2011	SOMERVELL			20110509
TX	SOMERVELL	TX4250990.40	J M LITTLE	1/18/2011	SOMERVELL			20110601
TX	SOMERVELL	TX4250990.41	BETTY ANN GRAHAM	1/6/2011	SOMERVELL			20110591
TX	SOMERVELL	TX4250990.42	SHERRY AMYX	2/3/2011	SOMERVELL			20110600
TX	SOMERVELL	TX4250990.43	JAMES LITTLE	2/16/2011	SOMERVELL			20110599
TX	SOMERVELL	TX4250990.44	ERNA YOUNG	3/4/2011	SOMERVELL			20110598
TX	SOMERVELL	TX4250990.45	PAM STAFFORD	3/9/2011	SOMERVELL			20110666
TX	SOMERVELL	TX4250990.46	CARLA GAMBINI	3/10/2011	SOMERVELL			20110667
TX	SOMERVELL	TX4250990.47	KIMBERLY LITTLE	3/16/2011	SOMERVELL			20110768
TX	SOMERVELL	TX4250990.48	CHARLES LITTLE	2/16/2011	SOMERVELL			20110712
TX	SOMERVELL	TX4250990.49	DAVID JACK GRAHAM	4/15/2011	SOMERVELL			20110949
TX	SOMERVELL	TX4250990.50	JERRY DAN GRAHAM JR	4/15/2011	SOMERVELL			20110950
TX	SOMERVELL	TX4250990.51	CAMELLIA ANN LIPSEY	4/21/2011	SOMERVELL			20111048
TX	SOMERVELL	TX4250990.52	JULIE D GRIFFIN	4/15/2011	SOMERVELL			20111051
TX	SOMERVELL	TX4250990.53	BRENDA I CARRIGAN	3/22/2011	SOMERVELL			20111036
TX	SOMERVELL	TX4250990.54	CHARLES D WARD	4/12/2011	SOMERVELL			20111040
TX	SOMERVELL	TX4250990.55	JERRY D WARD	4/25/2011	SOMERVELL			20111034
TX	SOMERVELL	TX4250990.56	GARY M CARRIGAN	5/1/2011	SOMERVELL			20111035
TX	SOMERVELL	TX4250990.57	RICHARD W CARRIGAN	4/15/2011	SOMERVELL			20111038
TX	SOMERVELL	TX4250990.58	HAROLD HARLAN KEENUM	3/14/2011	SOMERVELL			20111043
TX	SOMERVELL	TX4250990.59	RONNIE R SMETHERS	3/9/2011	SOMERVELL			20111041
TX	SOMERVELL	TX4250990.60	SHERRY ANN FRAZE	3/16/2011	SOMERVELL			20111042
TX	SOMERVELL	TX4250990.61	JO ANNA WILHITE	4/18/2011	SOMERVELL			20111027
TX	SOMERVELL	TX4250990.62	JAMES O JEFFCOAT	4/8/2011	SOMERVELL			20111049
TX	SOMERVELL	TX4250990.63	JASON LITTLE ET UX	3/8/2011	SOMERVELL			20111130
TX	SOMERVELL	TX4250990.64	SHARON A NASH	10/28/2011	SOMERVELL			20111985
TX	SOMERVELL	TX4250990.65	CANDACE ALLEN GARRETT	11/2/2010	SOMERVELL			20101951
TX	SOMERVELL	TX4250991.00	LORA M WARREN	11/30/2010	SOMERVELL			20110032
TX	SOMERVELL	TX4251008.01	DONALD NEIL WOMACK	2/22/2011	SOMERVELL			20110592
TX	SOMERVELL	TX4251008.02	HENRY C WOMACK III	2/22/2011	SOMERVELL			20110593
TX	SOMERVELL	TX4251008.03	CEDAR CREEEK LAND INC	5/17/2011	SOMERVELL			20111127
TX	SOMERVELL	TX4251008.04	JEFF C NOELL ET UX	11/2/2011	SOMERVELL			20120804
TX	SOMERVELL	TX4251008.05	GARY W KINSLOW ET UX	5/29/2012	SOMERVELL			20121401
TX	SOMERVELL	TX4251008.06	NANCY JANE WOMACK MOORE	2/22/2011	SOMERVELL			20110669
TX	SOMERVELL	TX4251008.07	NEW A MALIK INC	11/14/2012	SOMERVELL			20121852
TX	SOMERVELL	TX4251009.00	MARSHA COLLEEN BAKER	3/3/2011	SOMERVELL			20110602
TX	SOMERVELL	TX4251010.00	BILLY ANDERSON ET UX	3/10/2011	SOMERVELL			20110663
TX	SOMERVELL	TX4251014.00	BRENDA RANSOM ET VIR	3/21/2011	SOMERVELL			20110670
TX	SOMERVELL	TX4251015.00	BRENDA RANSOM EXECUTRIX OF THE ESTATE OF BILLY JEA	3/21/2011	SOMERVELL			20110671
TX	SOMERVELL	TX4251019.01	JOHN H HAYNIE JR	3/10/2011	SOMERVELL			20110878
TX	SOMERVELL	TX4251021.00	MICAL CUMMINGS ET AL	3/16/2011	SOMERVELL			20110877
TX	SOMERVELL	TX4251022.00	LARRY P SMITH	4/19/2011	SOMERVELL			20110881
TX	SOMERVELL	TX4251023.00	BOZIE WELLS ET UX	4/8/2011	SOMERVELL			20110879
TX	SOMERVELL	TX4251024.01	SANDRA BAKER COTTRELL	4/27/2011	SOMERVELL			20110882
TX	SOMERVELL	TX4251026.17	BILL CODY	5/31/2011	SOMERVELL			20111122
TX	SOMERVELL	TX4251026.18	JERRY D WHEATLEY ET UX	5/28/2014	SOMERVELL			20140883
TX	SOMERVELL	TX4251026.19	RUSSELL WHEATLEY	5/26/2014	SOMERVELL			20140884
TX	SOMERVELL	TX4251026.20	JOHNNY WHEATLEY ET UX	5/30/2014	SOMERVELL			20140995
TX	SOMERVELL	TX4251026.21	FREIDA LITTLEFIELD	5/30/2014	SOMERVELL			20140996
TX	SOMERVELL	TX4251026.22	NORMA JEAN RUSSELL	6/5/2014	SOMERVELL			20140993
TX	SOMERVELL	TX4251026.23	STEVEN PELLHAM	5/29/2014	SOMERVELL			20140992
TX	SOMERVELL	TX4251026.24	CARISSA LATO	5/29/2014	SOMERVELL			20140991
TX	SOMERVELL	TX4251026.25	MICHAEL DALE FORD ET UX	6/16/2014	SOMERVELL			20141079
TX	SOMERVELL	TX4251026.26	KELLY JO MCMILLAN	5/28/2014	SOMERVELL			20141078
TX	SOMERVELL	TX4251026.27	VIRGINIA R HALL	6/5/2014	SOMERVELL			20141077
TX	SOMERVELL	TX4251026.28	VESTA MARTINEZ & WHEATLEY ESTATE	6/20/2014	SOMERVELL			20141070
TX	SOMERVELL	TX4251026.29	SHARON TUNNELL	6/3/2014	SOMERVELL			20141071
TX	SOMERVELL	TX4251026.30	ALAN DALE ANGELEY	6/16/2014	SOMERVELL			20141208
TX	SOMERVELL	TX4251026.31	GLEE S WHEELER SUNTRUP	6/3/2014	SOMERVELL			20141213
TX	SOMERVELL	TX4251026.32	DAVID K JEFFERS ET UX	6/13/2014	SOMERVELL			20141296
TX	SOMERVELL	TX4251026.33	GALE R WHEELER ET VIR	6/3/2014	SOMERVELL			20141541
TX	SOMERVELL	TX4251027.01	TAMILEE NENNICH	4/1/2011	SOMERVELL			20110953
TX	SOMERVELL	TX4251028.00	WILLIAM R LAY	4/1/2011	SOMERVELL			20110954
TX	SOMERVELL	TX4251029.00	ST TX MF-112134	4/5/2011	SOMERVELL			20110856
TX	SOMERVELL	TX4251030.04	CHRISTOPHER MORRISON ET UX	8/22/2011	SOMERVELL			20111859
TX	SOMERVELL	TX4251031.00	RICHARD A NEILL ET UX	6/13/2011	SOMERVELL			20111203
TX	SOMERVELL	TX4251032.00	LARRY RUFUS VEST ET UX	6/21/2011	SOMERVELL			20111206
TX	SOMERVELL	TX4251034.00	CURTIS BUSCH ET UX	6/23/2011	SOMERVELL			20111297
TX	SOMERVELL	TX4251035.00	DOYLE T & EDNA M REEVES REVOCABLE LIVING TRUST	6/24/2011	SOMERVELL			20111299
TX	SOMERVELL	TX4251036.01	ORVILLE H MILLER	7/6/2011	SOMERVELL			20111293
TX	SOMERVELL	TX4251037.02	ELIZABETH ANN PARHAM	8/19/2014	SOMERVELL			20141660
TX	SOMERVELL	TX4251038.02	RILEY F GOSDIN ET UX	8/19/2014	SOMERVELL			20141661
TX	SOMERVELL	TX4251039.02	LARRY GOSDIN	8/19/2014	SOMERVELL			20141662
TX	SOMERVELL	TX4251040.02	WILLIAM HALE ET UX	8/19/2014	SOMERVELL			20141663
TX	SOMERVELL	TX4251041.07	GARY COUSINS ET UX	9/6/2011	SOMERVELL			20111793
TX	SOMERVELL	TX4251041.08	JOHNNIE R COUSINS JR ET UX	8/26/2011	SOMERVELL			20111794
TX	SOMERVELL	TX4251041.09	JOHN WINDER	8/4/2014	SOMERVELL			20141540
TX	SOMERVELL	TX4251041.10	CARRIE ANN BARTON-SMITH	8/6/2014	SOMERVELL			20141672
TX	SOMERVELL	TX4251041.11	BOBBIE JOAN MATHEWS	8/1/2014	SOMERVELL			20141670
TX	SOMERVELL	TX4251041.12	JANE ROSE	8/19/2014	SOMERVELL			20141668
TX	SOMERVELL	TX4251041.13	SHARON WINDER BILDERBACK	8/11/2014	SOMERVELL			20141664
TX	SOMERVELL	TX4251041.14	TIMOTHY MICHAEL SELLARS	8/1/2014	SOMERVELL			20141889
TX	SOMERVELL	TX4251041.15	DEBRA SELLARS NARVARTE	10/3/2014	SOMERVELL			20141973
TX	SOMERVELL	TX4251042.00	MILL AT SQUAW CREEK LLC	7/7/2011	SOMERVELL			20111384
TX	SOMERVELL	TX4251043.00	MILL AT SQUAW CREEK LLC	7/7/2011	SOMERVELL			20111383
TX	SOMERVELL	TX4251044.01	DOROTHY N MORRISON	6/28/2011	SOMERVELL			20111382
TX	SOMERVELL	TX4251045.01	DOROTHY N MORRISON	6/28/2011	SOMERVELL			20111379
TX	SOMERVELL	TX4251046.01	MANUEL DEREZA ET UX	6/28/2011	SOMERVELL			20111537
TX	SOMERVELL	TX4251049.00	GLENN RICHARDSON ET UX	7/12/2011	SOMERVELL			20111438
TX	SOMERVELL	TX4251050.00	LOWELL UNDERWOOD ET UX	7/5/2011	SOMERVELL			20111546
TX	SOMERVELL	TX4251051.00	KENT S LACEY ET UX	8/1/2011	SOMERVELL			20111542
TX	SOMERVELL	TX4251053.00	JAMES L STACY ET UX	8/15/2011	SOMERVELL			20111541
TX	SOMERVELL	TX4251057.00	ROBERT W MILLER ET UX	8/24/2011	SOMERVELL			20111788
TX	SOMERVELL	TX4251060.00	PRISCILLA TALLEY ET VIR	9/21/2011	SOMERVELL			20111857
TX	SOMERVELL	TX4251061.00	TOMMY PHILLIPS ET UX	10/4/2011	SOMERVELL			20111853
TX	SOMERVELL	TX4251062.00	MERLIN MUNDAY ET UX	8/29/2011	SOMERVELL			20111933
TX	SOMERVELL	TX4251063.00	JOSEPH CALVIN MCCOY ET UX	10/4/2011	SOMERVELL			20111856
TX	SOMERVELL	TX4251064.01	EDITH F KERNS	10/1/2011	SOMERVELL			20111935
TX	SOMERVELL	TX4251064.02	NATALIE A MODICA AKA NATALIE FEATHERSTON	10/1/2011	SOMERVELL			20112004
TX	SOMERVELL	TX4251065.00	JENNIFER J FOWLER	10/4/2011	SOMERVELL			20111936
TX	SOMERVELL	TX4251066.00	PHILLIP MAXWELL ET UX	10/4/2011	SOMERVELL			20111934
TX	SOMERVELL	TX4251070.00	JOHNNY MATTHEWS ET UX	1/9/2012	SOMERVELL			20120198
TX	SOMERVELL	TX4251071.00	WILLIAM E WYATT ET UX	2/15/2012	SOMERVELL			20120329
TX	SOMERVELL	TX4251072.00	JAMES R PARKS SR ET UX	2/21/2012	SOMERVELL			20120369
TX	SOMERVELL	TX4251074.00	DAVID MIMMS ET UX	3/1/2012	SOMERVELL			20120371
TX	SOMERVELL	TX4251075.00	KENNY M. RHODES	2/20/2012	SOMERVELL			20120473
TX	SOMERVELL	TX4251076.00	JESSE & MELISSA K SCHOESSOW	3/6/2012	SOMERVELL			20120472
TX	SOMERVELL	TX4251077.00	RON & JENNIFER FEEMSTER	3/6/2012	SOMERVELL			20120471
TX	SOMERVELL	TX4251079.00	NATHAN G. HUNTER	3/1/2012	SOMERVELL			20120504
TX	SOMERVELL	TX4251082.00	LOICE M KLIEM	4/5/2012	SOMERVELL			20121134
TX	SOMERVELL	TX4251084.00	SHEILA ANN ACKER	4/10/2012	SOMERVELL			20120857
TX	SOMERVELL	TX4251085.00	PATRICIA COPPOCK	5/24/2012	SOMERVELL			20120938
TX	SOMERVELL	TX4251087.00	EDGAR LEE WITT	6/19/2012	SOMERVELL			20121036
TX	SOMERVELL	TX4251092.00	LARRY P SMITH	7/26/2012	SOMERVELL			20121201
TX	SOMERVELL	TX4251093.00	LEOBARDO A MARTINEZ ET UX	10/2/2012	SOMERVELL			20121612
TX	SOMERVELL	TX4251094.99	JESSE K PRUITT	11/5/2012	SOMERVELL			20121809
TX	HOOD AND SOMERVELL	TX4251096.99	D SKJEVELAND / QRI	8/1/2013	HOOD			2013-0009581
TX	HOOD AND SOMERVELL	TX4251096.99	D SKJEVELAND / QRI	8/1/2013	SOMERVELL			20131299
TX	SOMERVELL	TX4251097.00	BENNY J HILLIARD ET UX	3/28/2014	SOMERVELL			20140471
TX	SOMERVELL	TX4251098.00	SOMERVELL COUNTY	4/15/2014	SOMERVELL			20140601
TX	SOMERVELL	TX4251099.00	SOMERVELL COUNTY	4/22/2014	SOMERVELL			20140758
TX	SOMERVELL	TX4251100.00	JEFFREY J DULCIE ET UX	6/7/2014	SOMERVELL			20141075
TX	SOMERVELL	TX4251101.00	KAROLEE WOLFE	6/23/2014	SOMERVELL			20141069
TX	SOMERVELL	TX4251102.00	JOHN A JOHNSON ET UX	6/20/2014	SOMERVELL			20141072
TX	SOMERVELL	TX4251103.00	LOVEDA PHIPPS SWAIM	6/19/2014	SOMERVELL			20141065
TX	SOMERVELL	TX4251104.00	MADELEINE SUE (PAT) WINDHAM	6/30/2014	SOMERVELL			20141209
TX	SOMERVELL	TX4251105.00	IRENE HOWARD JOLLY	6/24/2014	SOMERVELL			20141206
TX	SOMERVELL	TX4251106.00	ARTURO VILLA ET UX	7/15/2014	SOMERVELL			20141216
TX	SOMERVELL	TX4251107.00	SHARON LYNN MOSS	7/15/2014	SOMERVELL			20141215
TX	SOMERVELL	TX4251108.00	KRISTIE RENEE BROWN ET VIR	7/14/2014	SOMERVELL			20141211
TX	SOMERVELL	TX4251109.00	HANS T GEBHARDT	7/10/2014	SOMERVELL			20141217
TX	SOMERVELL	TX4251111.01	JANICE LEE COLEMAN	7/10/2014	SOMERVELL			20141306
TX	SOMERVELL	TX4251111.02	JEFFREY TAYLOR COLEMAN	7/10/2014	SOMERVELL			20141305
TX	SOMERVELL	TX4251111.03	JUSTIN WAYNE MILLER COLEMAN	7/10/2014	SOMERVELL			20141304
TX	SOMERVELL	TX4251112.00	JOHN L TUCKER	7/15/2014	SOMERVELL			20141308
TX	SOMERVELL	TX4251113.00	STEPHEN C WINDHAM ET UX	6/30/2014	SOMERVELL			20141312
TX	SOMERVELL	TX4251114.00	JACK DALE STEPHENS ET UX	7/19/2014	SOMERVELL			20141311
TX	SOMERVELL	TX4251115.00	STEVEN DALE BROWNEN ET UX	7/20/2014	SOMERVELL			20141314
TX	SOMERVELL	TX4251116.01	ROY TRENT SANDLIN	7/30/2014	SOMERVELL			20141302
TX	SOMERVELL	TX4251117.01	EUSEBIO GUZMAN EX UX	7/26/2014	SOMERVELL			20141303
TX	SOMERVELL	TX4251118.00	GREGORY A LITTLEFIELD ET UX	6/10/2014	SOMERVELL			20141297
TX	SOMERVELL	TX4251119.01	UNCLE GEORGE'S SPORTING GOODS	7/25/2014	SOMERVELL			20141300
TX	SOMERVELL	TX4251119.02	RAMON INGRAM BUNT ET UX	7/25/2014	SOMERVELL			20141295
TX	SOMERVELL	TX4251120.01	CARROLL B VALENTINE ET UX	7/30/2014	SOMERVELL			20141294
TX	SOMERVELL	TX4251120.02	JOSEPH B VALENTINE	7/30/2014	SOMERVELL			20141301
TX	SOMERVELL	TX4251121.01	EARL W DOYLE ET UX	7/8/2014	SOMERVELL			20141298
TX	SOMERVELL	TX4251122.01	ROBERT C RAU ET UX	7/17/2014	SOMERVELL			20141292
TX	SOMERVELL	TX4251122.02	RICHARD H RAU ET UX	7/18/2014	SOMERVELL			20141293
TX	SOMERVELL	TX4251123.00	SUZANNE GENTLING	6/30/2014	SOMERVELL			20141546
TX	SOMERVELL	TX4251124.00	KELLY W WATSON ET UX	6/26/2014	SOMERVELL			20141657
TX	SOMERVELL	TX4251125.01	DOVIE ANN GILLELAND	7/21/2014	SOMERVELL			20141543
TX	SOMERVELL	TX4251126.01	RUFUS MARTINEZ ESPINO ET UX	7/26/2014	SOMERVELL			20141545
TX	SOMERVELL	TX4251127.01	RUTH E ALEXANDER	8/5/2014	SOMERVELL			20141544
TX	SOMERVELL	TX4251127.02	CRAIG M CALKINS	8/5/2014	SOMERVELL			20141533
TX	SOMERVELL	TX4251128.01	ROBERT WAYNE WILLIAMS ET UX	8/9/2014	SOMERVELL			20141529
TX	SOMERVELL	TX4251129.01	MICHAEL GLASS ET UX	8/6/2014	SOMERVELL			20141534
TX	SOMERVELL	TX4251130.00	DAVID C BLASKO	7/10/2014	SOMERVELL			20141528
TX	SOMERVELL	TX4251131.00	ROBERT L NICKELL	8/4/2014	SOMERVELL			20141537
TX	SOMERVELL	TX4251132.00	BURL BYBEE ET UX	8/12/2014	SOMERVELL			20141539
TX	SOMERVELL	TX4251133.01	JOHN C CORNETT JR	8/5/2014	SOMERVELL			20141538
TX	SOMERVELL	TX4251134.01	JACOB R SMITH ET UX	8/9/2014	SOMERVELL			20141535
TX	SOMERVELL	TX4251135.01	WELBY R SIMPSON	8/14/2014	SOMERVELL			20141526
TX	SOMERVELL	TX4251135.02	GARY RAY HIVELY ET UX	8/26/2014	SOMERVELL			20141803
TX	SOMERVELL	TX4251135.03	CINDY L WATSON	8/26/2014	SOMERVELL			20141796
TX	SOMERVELL	TX4251136.01	ANN S TIBBETS	8/4/2014	SOMERVELL			20141677
TX	SOMERVELL	TX4251136.02	LISA A SOWALSKIE	8/12/2014	SOMERVELL			20141678
TX	SOMERVELL	TX4251137.00	TAMMY GAIL STINSON ET VIR	8/8/2014	SOMERVELL			20141673
TX	SOMERVELL	TX4251138.01	BEVERLY C JANZER BYRNE	8/25/2014	SOMERVELL			20141669
TX	SOMERVELL	TX4251138.02	DEBORAH LYNN BREWER	8/25/2014	SOMERVELL			20141665
TX	SOMERVELL	TX4251138.03	MIRIAM ELIZABETH MROZ	8/25/2014	SOMERVELL			20141666
TX	SOMERVELL	TX4251139.00	LISA JEAN DEHTAN	8/19/2014	SOMERVELL			20141675
TX	SOMERVELL	TX4251140.00	SHEILA D HOSFORD	8/29/2014	SOMERVELL			20141804
TX	SOMERVELL	TX4251141.01	EUGENE LEE DYAS ET UX	8/29/2014	SOMERVELL			20141799
TX	SOMERVELL	TX4251142.01	NANCY LEWIS ET VIR	8/28/2014	SOMERVELL			20141801
TX	SOMERVELL	TX4251143.01	CURTIS B BISE	9/15/2014	SOMERVELL			20141800
TX	SOMERVELL	TX4251144.00	C JEFFREY BISE & EUGENE DYAS	9/15/2014	SOMERVELL			20141890
TX	SOMERVELL	TX4251145.00	CINDY SPENCER	8/18/2014	SOMERVELL			20141891
TX	SOMERVELL	TX4251146.00	LOUIS M PIENAAR ET UX	9/4/2014	SOMERVELL			20141888
TX	SOMERVELL	TX4251147.01	MARK E SIMPSON ET UX	8/6/2014	SOMERVELL			20141969
TX	SOMERVELL	TX4251147.02	JOHN E SIMPSON JR	8/6/2014	SOMERVELL			20142146
TX	SOMERVELL	TX4251148.00	ROBERT C RANSOM	9/10/2014	SOMERVELL			20141977
TX	SOMERVELL	TX4251149.00	BRUCE LEON PILLAR ET UX	8/26/2014	SOMERVELL			20141978
TX	SOMERVELL	TX4251150.00	JOHN P THOMPSON JR ET UX	10/13/2014	SOMERVELL			20141971
TX	SOMERVELL	TX4251151.00	M MARKEYTA DEWEY	11/11/2014	SOMERVELL			20142145
TX	SOMERVELL	TX4251153.01	R W BAKER ET UX	10/10/2014	SOMERVELL			20142144
TX	SOMERVELL	TX4251154.01	JOHN W PRUITT	11/7/2014	SOMERVELL			20150124
TX	SOMERVELL	TX4251155.00	WAYNE MAC YOCHAM ET UX	12/16/2014	SOMERVELL			20150472
TX	SOMERVELL	TX4251156.01	JANE ROSE	11/7/2014	SOMERVELL			20150473
TX	SOMERVELL	TX4251156.02	JOHNNIE R COUSINS ET UX	11/7/2014	SOMERVELL			20150475
TX	SOMERVELL	TX4251156.03	SHARRON BILDERBACK	11/7/2014	SOMERVELL			20150474
TX	SOMERVELL	TX4251156.04	JOHN WINDER DDS	11/7/2014	SOMERVELL			20150476
TX	SOMERVELL	TX4251156.05	DEBRA SELLARS NARVARTE	11/13/2014	SOMERVELL			20150471
TX	SOMERVELL	TX4251156.06	BOBBIE JOAN MATTHEWS	11/13/2014	SOMERVELL			20150470
TX	SOMERVELL	TX4251158.00	PATRICK K SANDERS	9/19/2015	SOMERVELL			20160014

EXHIBIT B TO THE

GAS GATHERING AND PROCESSING AGREEMENT

[COWTOWN GAS FACILITIES]

GATHERING SYSTEM DELIVERY POINTS

This Exhibit B is attached to the Gas Gathering and Processing Agreement (the "Agreement") dated effective April 1, 2016 by and among BlueStone Natural Resources II, LLC, Cowtown Pipeline Partners L.P., and Cowtown Gas Processing Partners L.P. and made a part thereof for all purposes. All defined terms used herein shall have the same meaning as set forth in the Agreement.

Gathering System Delivery Point(s)

Gathering System Delivery Point	Survey	API#
See attached schedule

Plant Delivery Point(s)

Plant Delivery Point	Survey	Meter#
Cowtown Gas Processing Partners L.P.		TXSA004

ATTACHED TO EXHIBIT B TO GAS GATHERING AND PROESSING AGREEMENT

Ownership	Sales Meter Name	Meter #	Active?
CMLP	ACTON MEADOWS 1-2 SALES	TX15911	Active
CMLP/QRI	ADAM STINSON 1H	TX30223	Active
CMLP/QRI	ADAM STINSON 4H	TX30225	Active
CMLP/QRI	ADAM STINSON 5H	TX30226	Active
CMLP/QRI	ADAM STINSON 6H	TX30227	Active
CMLP/QRI	ADAM STINSON 7H	TX30228	Active
CMLP/QRI	ADAM STINSON 11H	TX30230	Active
CMLP/QRI	ADAM STINSON 12H	TX30231	Active
CMLP/QRI	APU 3H	TX30125	Active
CMLP/QRI	APU 4H	TX30124	Active
CMLP	APU 5-6 SALES	TX20977	Active
CMLP/QRI	APU 7H	TX16660	Active
CMLP/QRI	APU 8H	TX30198	Active
CMLP/QRI	APU 9H	TX30196	Active
CMLP/QRI	APU 10H	TX30199	Active
CMLP	ARMSTRONG 1-3 SALES	TX30146	Active
CMLP	ARMSTRONG 4-6 SALES	TX30138	Active
CMLP	BARKER COFFMAN 5H SALES	TX30248	Active
CMLP	BARKER COFFMAN 6H SALES	TX30249	Active
CMLP	BARKER COFFMAN 7H SALES	TX30243	Active
CMLP/QRI	BARKER COFFMAN 11H	TX30247	Active
CMLP/QRI	BARNEY GUMBLE 1H	TX15432	Active
CMLP	BERLIN 1-2 SALES	TX20617	Active
CMLP	BERLIN 3-7 SALES	TX20618	Active
CMLP	BIG ROCK 1-9 SALES	TX31306	Active
CMLP	BILLIE HOLIDAY 1-3 SALES	TX30157	Active
CMLP	BLUE DUCK 1H SALES	TX20629	Active
CMLP/QRI	BOB DENVER 1H	TX31093	Active
CMLP/QRI	BOB DENVER 3H	TX31240	Active
CMLP	BOB DENVER 5-7 SALES	TX31229	Active
CMLP/QRI	BOB HARRIS 1H	TX30203	Active
CMLP/QRI	BOB HARRIS 2H	TX16702	Active
CMLP/QRI	BOB HARRIS 3H	TX30202	Active
CMLP	BOY SCOUT 1-2 SALES	TX31184	Active
CMLP	BOY SCOUT 3-5 SALES	TX31207	Active
CMLP/QRI	BRANHAM KELLER 1H	TX30190	Active
CMLP/QRI	BRANHAM KELLER 2H	TX30272	Active
CMLP/QRI	BRANHAM KELLER 3H	TX30273	Active
CMLP/QRI	BRANHAM KELLER 4H	TX16839	Active
CMLP/QRI	BRANHAM KELLER 5H	TX30278	Active
CMLP/QRI	BROWN EYED GIRL 1H	TX31076	Active
CMLP/QRI	BROWN EYED GIRL 2H	TX31715	Active
CMLP/QRI	BROWN EYED GIRL 3H	TX31714	Active
CMLP/QRI	BROWN EYED GIRL 4H	TX31716	Active
CMLP/QRI	BROWN HILL 1H	TX31683	Active
CMLP/QRI	BROWN HILL 2H	TX31682	Active
CMLP	BUBBS SALES	TX20365	Active
QRI	BUBBS VRU	TX21001	Active
CMLP	BYRL HAYWORTH 1-4 SALES	TX21045	Active
CMLP	BYRL HAYWORTH 5-7 SALES	TX21046	Active
CMLP	CAMPOS A 1-6 SALES	TX31045	Active
CMLP	CAMPOS B 1-6 SALES	TX31053	Active
CMLP	CARL CARLSON 1-3 SALES	TX31363	Active
CMLP/QRI	CAUBLE 1H	TX31208	Active
CMLP/QRI	CAUBLE 2H	TX31172	Active
CMLP/QRI	CAVEN 1H	TX31805	Active
CMLP/QRI	CAVEN 2H	TX31811	Active
CMLP/QRI	CAVEN 3H	TX31806	Active
CMLP/QRI	CAVEN 6H	TX31808	Active
CMLP/QRI	CHARCA LIMITED 1H	TX30197	Active
CMLP/QRI	CHARCA LIMITED 2H	TX30201	Active
CMLP/QRI	CHARCA-HANGER 1H	TX30983	Active
CMLP/QRI	CHARCA-HANGER 2H	TX34318	Active
CMLP/QRI	CHARCA-HANGER 3H	TX34165	Active
CMLP	CHESBROUGH SHAW 1-2 SALES	TX20453	Active
CMLP	CHESBROUGH SHAW 3-5 SALES	TX20454	Active
CMLP/QRI	CHRISSY 1H	TX31091	Active
CMLP	COLONEL FLAGG 1-3 SALES	TX20522	Active
CMLP	COLONEL FLAGG 4-7 SALES	TX20501	Active
CMLP/QRI	COYOTE CROSSING 1H	TX31083	Active
CMLP/QRI	COYOTE CROSSING 2H	TX31856	Active
CMLP/QRI	CRABTREE 6H	TX31795	Active
CMLP	DEBORAH LOU 1-2 SALES	TX20564	Active
CMLP	DEBORAH LOU 3-4 SALES	TX20565	Active
CMLP	DEBORAH LOU 5-6 SALES	TX20566	Active
CMLP	DEBORAH LOU 7-9 SALES	TX20567	Active
CMLP	DECORDOVA 8H SALES	TX31824	Active
CMLP/QRI	DIZZY GILLESPIE 1H	TX30129	Active
CMLP/QRI	DONALD TALLMAN 1H	TX30216	Active
CMLP/QRI	DONALD TALLMAN 2H	TX30220	Active
CMLP/QRI	DONALD TALLMAN 4H	TX30218	Active
CMLP/QRI	DONALD TALLMAN 5H	TX30222	Active
CMLP/QRI	DONALD TALLMAN 6H	TX30219	Active
CMLP/QRI	DORIS FINLEY 1H	TX31727	Active
CMLP/QRI	DORIS FINLEY 2H	TX31728	Active
CMLP/QRI	DORIS FINLEY 4H	TX31730	Active
CMLP/QRI	DUGGER HEWLETT NORTH 1H	TX30186	Active
CMLP/QRI	DUGGER HEWLETT NORTH 2H	TX30180	Active
CMLP/QRI	DUGGER HEWLETT NORTH 3H	TX30181	Active
CMLP/QRI	DUGGER HEWLETT NORTH 4H	TX30182	Active
CMLP/QRI	DUGGER HEWLETT NORTH 5H	TX30183	Active
CMLP/QRI	DUGGER HEWLETT NORTH 6H	TX30184	Active
CMLP/QRI	DUGGER HEWLETT NORTH 7H	TX30185	Active
CMLP/QRI	DUGGER HEWLETT SOUTH 1	TX30206	Active
CMLP/QRI	DUGGER HEWLETT SOUTH 2H	TX30207	Active
CMLP/QRI	DUGGER HEWLETT SOUTH 3H	TX30204	Active
CMLP/QRI	DUGGER HEWLETT SOUTH 4H	TX30209	Active
CMLP/QRI	DUGGER HEWLETT SOUTH 5H	TX30205	Active
CMLP/QRI	DUGGER HEWLETT SOUTH 6H	TX30208	Active
CMLP/QRI	DUGGER HEWLETT SOUTH 7H	TX16824	Active
CMLP/QRI	DYER 1H	TX31830	Active
CMLP/QRI	DYER 2H	TX31887	Active
CMLP/QRI	DYER 3H	TX31889	Active
CMLP/QRI	DYER 4H	TX31888	Active
CMLP/QRI	EL CAMINO 1H	TX31176	Active
CMLP/QRI	FREELAND 1H	TX30277	Active
CMLP/QRI	FREELAND 2H	TX30330	Active
CMLP/QRI	FREELAND 3H	TX24339	Active
CMLP	GERALD FORD 1-2 SALES	TX30150	Active
CMLP/QRI	GIBBS 1H	TX31010	Active
CMLP/QRI	GIBBS 2H	TX31009	Active
CMLP/QRI	GIBBS 3H	TX31600	Active
CMLP/QRI	GIBBS 4H	TX31601	Active
CMLP/QRI	GILLIGAN 1H	TX31030	Active
CMLP	GILLIGAN 2-5 SALES	TX31222	Active
CMLP	GLEEN 1-6 SALES	TX20504	Active
CMLP/QRI	GOFF 1H	TX30265	Active
CMLP/QRI	GRACIE 4H	TX31768	Active
CMLP/QRI	GRACIE 5H	TX31772	Active
CMLP/QRI	GRACIE 6H	TX31769	Active
CMLP/QRI	GREGORY FAMILY TRUST 1H	TX30255	Active
CMLP/QRI	GREGORY FAMILY TRUST 2H	TX30256	Active
CMLP/QRI	GREGORY FAMILY TRUST 3H	TX30257	Active
CMLP/QRI	GREGORY FAMILY TRUST 4	TX30258	Active
CMLP/QRI	HANGER TRUST 1H	TX30303	Active
CMLP	HARRELL HOD CDP	TX21602	Active
CMLP/QRI	HARRIS LANGFORD 1H	TX31844	Active
CMLP/QRI	HARRIS LANGFORD 2H	TX31845	Active
CMLP	HAWKEYE 2-3 SALES	TX20516	Active
CMLP/QRI	HAYWIRE 1H	TX31096	Active
CMLP/QRI	HAYWORTH 1H	TX31046	Active
QRI	HENRY ZWEIFUL 1H	TX31726	Active
CMLP/QRI	HOFFMAN 1H	TX31934	Active
CMLP/QRI	HOFFMAN 3H	TX31935	Active
CMLP/QRI	HOFFMAN 4H	TX31936	Active
CMLP	HONEYCOMB 1-4 SALES	TX31295	Active
CMLP	HOODENPYLE 1 SALES	TX30275	Active
CMLP	HOOVER 1-7 SALES	TX20630	Active
CMLP	HOOVER 8-9 SALES	TX20626	Active
CMLP	HOOVER 10-12 SALES	TX20627	Active
CMLP/QRI	HOT LIPS 4H	TX31699	Active
CMLP/QRI	HOT LIPS 5H	TX31700	Active
CMLP	HOT LIPS/HAWKEYE SALES	TX20605	Active
CMLP	HUMMER 1-2 SALES	TX20400	Active
CMLP	JAMES 1H SALES	TX20472	Active
CMLP	JAMES 2-3 SALES	TX20484	Active
CMLP/QRI	JAMES B. MOONEY 1H	TX32898	Active
CMLP/QRI	JAMES B. MOONEY 2H	TX33688	Active
CMLP/QRI	JOHN J MILES 2H	TX30284	Active
CMLP/QRI	JOHN J. MILES 5H	TX33269	Active
CMLP/QRI	JOHN J. MILES 6H	TX34203	Active
CMLP/QRI	JULIA ROSE 2H	TX31820	Active
CMLP/QRI	KAMELL 1H	TX31749	Active
CMLP/QRI	KAMELL 2H	TX31750	Active
CMLP/QRI	KAMELL 3H	TX31747	Active
CMLP/QRI	KAMELL 4H	TX31748	Active
CMLP	KEITH-RANDLE 1H SALES	TX20674	Active
CMLP/QRI	KIMMEL 1H	TX31102	Active
CMLP	KINNARD 1-3 SALES (RODRIGO-KINNARD)	TX20958	Active
CMLP	KR MIXER 1-2 SALES	TX20418	Active
CMLP	KR MIXER 3-4 SALES	TX20419	Active
CMLP/QRI	LA FRANCE 1H	TX31058	Active
CMLP	LA FRANCE 3H SALES	TX31876	Active
CMLP	LA FRANCE 4H SALES	TX31877	Active
CMLP	LANGDON 1-4 SALES	TX30994	Active
CMLP	LANGDON A 1-2 SALES	TX20509	Active
CMLP	LANGDON A 3-4 SALES	TX20503	Active
CMLP/QRI	LANGDON B 1H	TX31042	Active
CMLP/QRI	LANGDON B 2H	TX31904	Active
CMLP/QRI	LANGDON B/STEWART 1H	TX31913	Active
CMLP/QRI	LANGDON B/STEWART 2H	TX31914	Active
CMLP/QRI	LANGDON B/STEWART 3H	TX31915	Active
CMLP	LOVEY 1H SALES	TX15295	Active
CMLP	LOVEY 2H SALES	TX16017	Active
CMLP/QRI	LUCY 1	TX31018	Active
CMLP/QRI	LUCY 2	TX31089	Active
CMLP	LUKER HAMMER 1-5 SALES	TX20628	Active
CMLP/QRI	MABEL ROE 1H	TX31169	Active
CMLP/QRI	MABEL ROE 2H	TX31170	Active
CMLP/QRI	MABERY 1H	TX31866	Active
CMLP	MAJOR BURNS 1-2 SALES	TX20515	Active
CMLP/QRI	MARSALIS 1H	TX30136	Active
CMLP/QRI	MARY ANN 1H	TX30999	Active
CMLP/QRI	MARY ANN 2H	TX30985	Active
CMLP/QRI	MARY ANN 4H	TX31641	Active
CMLP/QRI	MARY ANN 5H	TX31666	Active
CMLP/QRI	MARY ANN 6H	TX31665	Active
CMLP/QRI	MASSEY 1H	TX31047	Active
CMLP/QRI	MASSEY 2H	TX31050	Active
CMLP/QRI	MCGILVERY 1H	TX31761	Active
CMLP	MCGILVERY 2H SALES	TX31865	Active
CMLP	MCGILVERY 4H SALES	TX31764	Active
CMLP/QRI	MILES/DAVIS 1H	TX30131	Active
CMLP	MILLARD FILLMORE SALES	TX21451	Active
CMLP/QRI	MILLSTREAM 4H	TX31831	Active
CMLP/QRI	MILLSTREAM 5H	TX31799	Active
CMLP/QRI	MILLSTREAM 6H	TX31800	Active
CMLP/QRI	MILLSTREAM B 7	TX31869	Active
CMLP/QRI	MILLSTREAM B-8	TX31870	Active
CMLP/QRI	MILLSTREAM B-9	TX31871	Active
CMLP	MONK 1-3 SALES	TX30149	Active
CMLP/QRI	MONTE CARLO 1H	TX31146	Active
CMLP/QRI	MONTE CARLO 2H	TX31164	Active
CMLP/QRI	MONTGOMERY BURNS 1H	TX30589	Active
CMLP	MOONEY A 1/3 SALES	TX20437	Active
CMLP	MOONEY A 2H SALES	TX16021	Active
CMLP	MOONEY B 1-3 SALES	TX20438	Active
CMLP	MUTLEY 1H SALES	TX20534	Active
CMLP	NIMROD 1H SALES	TX20595	Active
CMLP	NOEL 1-3 SALES	TX20428	Active
CMLP	PALLMEYER A 1-3 SALES	TX31036	Active
CMLP	PALLMEYER B/LADD SALES	TX31051	Active
CMLP/QRI	PALLMEYER EAST 1H	TX31217	Active
CMLP	PARKER 1-6 SALES	TX31037	Active
CMLP/QRI	POSSUM HOLLER 1H	TX31177	Active
CMLP/QRI	POSSUM HOLLER 2H	TX31187	Active
CMLP	PRICE 1-6 SALES	TX20599	Active
CMLP	PRICE 7-10 SALES	TX20600	Active
CMLP/QRI	PROFESSOR 1H	TX30995	Active
CMLP/QRI	PROFESSOR 2H	TX30984	Active
CMLP/QRI	PROFESSOR 3H	TX31640	Active
CMLP/QRI	PROFESSOR 4H	TX31642	Active
CMLP	RADAR 1-5 SALES	TX20402	Active
CMLP/QRI	RADAR WEST 2H	TX31848	Active
CMLP	RALPH WIGGUM 5-6 SALES	TX20479	Active
CMLP	RALPH WIGGUM 7-8 SALES	TX20480	Active
CMLP	RALPH WIGGUM 9-10 & 13-15 SALES	TX20481	Active
CMLP	RALPH WIGGUM 1-4/11-12 SALES	TX31099	Active
CMLP	RANDLE 1-3 SALES	TX31248	Active
CMLP	RANDLE 4-6 SALES	TX31252	Active
CMLP/QRI	REBECCA BROWN KELLER 1H	TX30236	Active
CMLP/QRI	REBECCA BROWN KELLER 2H	TX30233	Active
CMLP/QRI	REBECCA BROWN KELLER 3H	TX30234	Active
CMLP/QRI	REBECCA BROWN KELLER 4H	TX30235	Active
CMLP/QRI	REBECCA BROWN KELLER 5H	TX30237	Active
CMLP/QRI	REBECCA BROWN KELLER 6H	TX30238	Active
CMLP/QRI	REBECCA BROWN KELLER 7H	TX30239	Active
CMLP/QRI	RED DRAGON 1H	TX31077	Active
CMLP/QRI	RED DRAGON 2H	TX31078	Active
CMLP	RED DRAGON 3H-4H SALES	TX20496	Active
CMLP	ROSIE 1-2 SALES	TX20535	Active
CMLP/QRI	SAM MARSHALL 1H	TX31022	Active
CMLP/QRI	SAM MARSHALL 2H	TX31049	Active
CMLP/QRI	SAM MARSHALL A 1H	TX31111	Active
CMLP/QRI	SAM MARSHALL A 2H	TX31163	Active
CMLP	SAN RAPHAEL 1-4 SALES	TX31198	Active
CMLP	SASS 1-7 SALES	TX20455	Active
CMLP/QRI	SATCHMO 1H	TX30117	Active
CMLP/QRI	SATCHMO 2H	TX30179	Active
CMLP/QRI	SATCHMO 3H	TX30177	Active
CMLP/QRI	SATCHMO 4H	TX30178	Active
CMLP/QRI	SEXTON 3H	TX30264	Active
CMLP	SHERRI P 2 & 4 SALES	TX20543	Active
CMLP	SHERRI P 6 & 8 SALES	TX20544	Active
CMLP	SHIPLEY 1-2 SALES	TX20650	Active
CMLP/QRI	SILVER BULLET 2H	TX31626	Active
CMLP/QRI	SILVER BULLET 4H	TX31854	Active
CMLP	SILVER BULLET 5-6 SALES	TX20933	Active
CMLP/QRI	SKIPPER 1H	TX31244	Active
CMLP/QRI	SKIPPER 2H	TX31234	Active
CMLP/QRI	SKIPPER 4H	TX31256	Active
CMLP/QRI	SKIPPER 5H	TX31257	Active
CMLP/QRI	SMELLEY 1H	TX31003	Active
CMLP/QRI	SPEED RACER 1H	TX31004	Active
CMLP/QRI	SPEEDRACER 3H	TX34413	Active
CMLP	SPUDS 1H SALES	TX15841	Active
CMLP/QRI	SS MINNOW 1H	TX31165	Active
CMLP	STATION BRANCH 1H SALES	TX20644	Active
CMLP	STATION BRANCH 2-3 SALES	TX20645	Active
CMLP	STATION BRANCH 4-6 SALES	TX20646	Active
CMLP	STATION BRANCH 7H SALES	TX20647	Active
CMLP	STATION BRANCH 8-10 SALES	TX20648	Active
CMLP	STATION BRANCH 11-12 SALES	TX20649	Active
CMLP	STETSON MASSEY 1-4 SALES	TX20531	Active
CMLP	STETSON MASSEY 5H SALES	TX20532	Active
CMLP	STEWART 1-2 SALES	TX20510	Active
CMLP/QRI	STINGRAY 2H	TX31825	Active
CMLP/QRI	STINGRAY 5H	TX31826	Active
CMLP/QRI	SUGARCRISP 1H	TX31084	Active
CMLP/QRI	SUGARCRISP 2H	TX31085	Active
CMLP	SUGARCRISP 3H SALES	TX31301	Active
CMLP	SUGARCRISP 4H SALES	TX31302	Active
CMLP	SUGARCRISP 5H SALES	TX31291	Active
CMLP/QRI	SUNNYE 1H	TX31148	Active
CMLP/QRI	SUNNYE 2H	TX31149	Active
CMLP	T & P 1/ 5/ 6 SALES	TX20596	Active
CMLP	T & P 2 & 7 SALES	TX20597	Active
CMLP	T & P 3-4 SALES	TX20598	Active
CMLP/QRI	TEJAS WESTERN 1H	TX31104	Active
CMLP/QRI	THURSTON 1H	TX31142	Active
CMLP/QRI	THURSTON 2H	TX31154	Active
CMLP/QRI	THURSTON 3H	TX31155	Active
CMLP	TRAPPER JOHN 1/2/4 SALES	TX20500	Active
CMLP	TRAPPER JOHN 3H SALES	TX20521	Active
CMLP/QRI	UNIMIN 2H	TX30253	Active
CMLP/QRI	UNIMIN 3H	TX30251	Active
CMLP	VETTE 1-5 SALES	TX31024	Active
CMLP	WAYLON SMITHERS 3-4 SALES	TX20440	Active
CMLP	WHEELER 1-3 SALES	TX20994	Active
CMLP	WHEELER 4-5 SALES	TX20995	Active
CMLP	WILLIAM FINN 1-2 SALES	TX20525	Active
CMLP	WILLIAM FINN 3-5 SALES	TX20526	Active
CMLP	YOSEMITE SAM 1-2 SALES	TX20491	Active
CMLP	YOSEMITE SAM 4-5 SALES	TX20493	Active
CMLP	YOSEMITE SAM 6-8 SALES	TX20494	Active
CMLP/QRI	ZBAR 1H	TX30992	Active
CMLP	ZBAR 2-3 SALES	TX20502	Active
CMLP/QRI	APU 1H	TX30119	Inactive
CMLP/QRI	APU 2H	TX30127	Inactive
CMLP/QRI	BIG ROCK VRU	TX21018	Inactive
CMLP/QRI	BOB DENVER 2H	TX31095	Inactive
CMLP/QRI	BOB DENVER 4H	TX31239	Inactive
CMLP/QRI	CHARCA LIMITED 3H	TX30210	Inactive
CMLP	CORVETTE RESIDUE	TXSA012	Inactive
QRI	DECORDOVA CBT VRU	TX21019	Inactive
CMLP/QRI	DUGGER HEWLETT SOUTH 8H	TX30211	Inactive
CMLP/QRI	DUGGER HEWLETT SOUTH 9H	TX30212	Inactive
CMLP/QRI	ELLA 1H	TX30133	Inactive
CMLP/QRI	ELLA 2H	TX30134	Inactive
CMLP/QRI	ELLA 3H	TX30135	Inactive
QRI	HAWKEYE #2H	TX31110	Inactive
CMLP/QRI	HAYWIRE 2H	TX31178	Inactive
CMLP/QRI	HINTON 1H	TX31092	Inactive
CMLP/QRI	HINTON 2H	TX31236	Inactive
CMLP/QRI	HINTON 3H	TX31237	Inactive
CMLP/QRI	HOMER #1H	TX30604	Inactive
CMLP/QRI	JOHN J MILES 1H	TX30106	Inactive
CMLP/QRI	JOHN J MILES 4H	TX30368	Inactive
CMLP/QRI	LA FRANCE 2H	TX31057	Inactive
CMLP	LENNY LEONARD 1H SALES	TX15449	Inactive
CMLP	LEWELLEN 1H SALES	TX20536	Inactive
CMLP	LEWELLEN 2-4 SALES	TX20537	Inactive
CMLP/QRI	LUMINANT 2H	TX30261	Inactive
CMLP/QRI	MARY ANN 3H	TX31639	Inactive
CMLP/QRI	NIXON UNIT #1H	TX30113	Inactive
CMLP/QRI	POSSUM HOLLER 3H	TX31190	Inactive
CMLP/QRI	POSSUM HOLLER 4H	TX31192	Inactive
CMLP	RADAR #3H SALES	TX20508	Inactive
CMLP	SHANNON PARKER 1/2/4 SALES	TX20576	Inactive
CMLP/QRI	SILVER BULLET 1H	TX31853	Inactive
CMLP/QRI	SILVER BULLET 3H	TX31855	Inactive
CMLP/QRI	SMELLEY 2H	TX31153	Inactive
CMLP/QRI	SMELLEY B-1H	TX31145	Inactive
CMLP/QRI	SPEED RACER 2D	TX31090	Inactive
CMLP	STEWART 3H SALES	TX20511	Inactive
CMLP/QRI	STINGRAY 1H	TX31897	Inactive
CMLP/QRI	STINGRAY 3H	TX31898	Inactive
CMLP	WAYLON SMITHERS 1-2 SALES	TX20439	Inactive
CMLP	WELLMAN 1-3 SALES	TX20401	Inactive
CMLP	WHEELER 4 SALES	TX31707	Inactive
CMLP/QRI	WOODROW WILSON #1H	TX30126	Inactive
CMLP	YOSEMITE SAM 3H SALES	TX20492	Inactive

To the extent the parties hereto have inadvertently omitted a dedicated property, such property shall be deemed covered under this Agreement and included in this Exhibit B.

EXHIBIT C TO THE

GAS GATHERING AND PROCESSING AGREEMENT

[COWTOWN GAS FACILITIES]

RESIDUE AND PLANT PRODUCT REDELIVERY POINTS

This Exhibit C is attached to the Gas Gathering and Processing Agreement (the "Agreement") dated effective April 1, 2016 by and among BlueStone Natural Resources II, LLC, Cowtown Pipeline Partners LP., and Cowtown Gas Processing Partners L.P. and made a part thereof for all purposes. All defined terms used herein shall have the same meaning as set forth in the Agreement.

Residue Gas Delivery Point(s)

Downstream Operator	Meter Name	Meter #
Atmos	“Cowtown Pipeline Partners”	18203800
Energy Transfer	“Quicksilver Cowtown”	009911-00
Enterprise Products	“Quicksilver Cowtown”	533295

Plant Products Delivery Point

Downstream Operator	Meter Name	Meter #
ONEOK West Texas LPG Pipeline		38010
ONEOK Arbuckle Pipeline
Energy Transfer Lonestar NGL

EXHIBIT D TO THE

GAS GATHERING AND PROCESSING AGREEMENT

[COWTOWN GAS FACILITIES]

EXCLUDED SHUT-IN WELLS

This Exhibit D is attached to the Gas Gathering and Processing Agreement (the "Agreement") dated effective April 1, 2016 by and among BlueStone Natural Resources II, LLC, Cowtown Pipeline Partners L.P., and Cowtown Gas Processing Partners L.P. and made a part thereof for all purposes. All defined terms used herein shall have the same meaning as set forth in the Agreement.

AREA	WELL
BARNETT - SOUTH	BYRL HAYWORTH 2H
BARNETT - SOUTH	DORRIS FINLEY 4H
BARNETT - SOUTH	HOOVER UNIT 6H
BARNETT - SOUTH	HOOVER UNIT 7H
BARNETT - SOUTH	JULIA ROSE 2H
BARNETT - SOUTH	RALPH WIGGUM 4H
BARNETT - SOUTH	WHEELER 1H

EXHIBIT E TO THE

GAS GATHERING AND PROCESSING AGREEMENT

[COWTOWN GAS FACILITIES]

MASH UNIT

This Exhibit E is attached to the Gas Gathering and Processing Agreement (the "Agreement") dated effective April 1, 2016 by and among BlueStone Natural Resources II, LLC, Cowtown Pipeline Partners L.P., and Cowtown Gas Processing Partners L.P. and made a part thereof for ail purposes. All defined terms used herein shall have the same meaning as set forth in the Agreement.

WELLS:

The following wells located in Hood County, Texas:

Well NameWell ID

HAWKEYE1H        42.1021.001

HAWKEYE2H        42.1021.011

HAWKEYE 3H        42.1021.024

HOT LIPS 1H            42.1021.002

HOT LIPS 2H            42.1021.028

HOT LIPS 3H            42.1021.029

MAJOR BURNS 1H        42.1021.006

MAJOR BURNS 2H        42.1021.025

TRAPPER JOHN 1H        42.1021.004

TRAPPER JOHN 2H        42.1021.005

TRAPPER JOHN 4H        42.1021.023

COLONEL FLAGG 1H    42.1021.007

COLONEL FLAGG 2H    42.1021.008

COLONEL FLAGG3H    42.1021.017

REDELIVERY POINTS:

Redelivery Points
Well Name		Well ID	Injection #
HAWKEYE1H	INJ	42.1021.001	TX 30993INJ
HAWKEYE 2H	INJ	42.1021.011	TX 31112INJ
HAWKEYE 3H	INJ	42.1021.024	TX 31462INJ
HOT LIPS 1H	INJ	42.1021.002	TX 30988INJ
HOT LIPS 2H	INJ	42.1021.028	TX 31588INJ
HOT LIPS 3H	INJ	42.1021.029	TX 31589INJ
MAJOR BURNS 1H	INJ	42.1021.006	TX 31007INJ
MAJOR BURNS 2H	INJ	42.1021.025	TX 31466 INJ
TRAPPER JOHN 1H	INJ	42.1021.004	TX 30986INJ
TRAPPER JOHN 2H	INJ	42.1021.005	TX 30987INJ
TRAPPER JOHN 4H	INJ	42.1021.023	TX 31465INJ
COLONEL FLAGG1H	INJ	42.1021.007	TX 31020INJ
COLONEL FLAGG 2H	INJ	42.1021.008	TX 31019 INJ
COLONEL FLAGG 3H	INJ	42.1021.017	TX 31463 INJ

EXHIBIT F TO THE

GAS GATHERING AND PROCESSING AGREEMENT

[COWTOWN GAS FACILITIES]

TAKE-IN-KIND PROCEDURES

This Exhibit F is attached to the Gas Gathering and Processing Agreement (the "Agreement") dated effective April 1, 2016 by and among BlueStone Natural Resources II, LLC, Cowtown Pipeline Partners L.P., and Cowtown Gas Processing Partners L.P. and made a part thereof for all purposes. All defined terms used herein shall have the same meaning as set forth in the Agreement.

Producer shall take its Plant Products in-kind at the Plant Products Delivery Points subject to the following terms and conditions (the “TIK Procedures”):

1.    Designation of Volumes at Delivery Points. Producer shall designate the volume to be delivered at each Plant Products Delivery Point.

2.    Producer Responsible for Transportation Arrangements. Producer shall be responsible for making its own arrangements with the transporters accepting delivery at the Plant Products Delivery Points for the receipt, transportation and fractionation of such Plant Products. Control and possession of Producer's Plant Products shall pass to Producer when delivered at the Plant Products Delivery Points, and the indemnification provided by Producer to Processor and Gatherer pursuant to Section 17.2 of the Agreement shall be applicable at such time as the Plant Products pass through the Plant Products Delivery Points.

3.    Balancing Accounting. Processor will maintain an "over/under" account to reflect any imbalances as between the parties. Processor shall provide Producer with a statement each Month setting forth the amounts of any imbalances for "over-delivered" or "under-delivered" quantities during the preceding Month.

4.    Balancing of Deliveries. Producer and Processor recognize Processor's inability to redeliver Plant Products to Producer which exactly match the composition and quantities of the Plant Products. In-kind quantities of Plant Products due to Producer shall be delivered in, and as part of, the commingled stream of all plant products produced or extracted at the Plant. Processor and Producer shall make a good faith effort to keep the nominated and delivered quantities as much in balance as possible by making delivery adjustments from time to time.

5.    Producer Responsible for Payments. Producer shall account to and pay all interest owners for all royalties, overriding royalties, bonus payments, production payments and other payments due on Plant Products taken in-kind by Producer, and the indemnification provided by Producer to Gatherer and Processor in Section 14.4 of the Agreement shall be applicable to and include any such payments due with respect to same.

6.    Assignment. The TIK procedures set forth herein may not be severed and assigned in part or separately from the Subject Gas and the Contract Area.

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EXHIBIT G TO THE

GAS GATHERING AND PROCESSING AGREEMENT

[COWTOWN GAS FACILITIES]

COMPRESSION ADJUSTMENTS

This Exhibit G is attached to the Gas Gathering and Processing Agreement (the "Agreement") dated effective April 1, 2016 by and among BlueStone Natural Resources II, LLC, Cowtown Pipeline Partners L.P., and Cowtown Gas Processing Partners L.P. and made a part thereof for ail purposes. All defined terms used herein shall have the same meaning as set forth in the Agreement.

Pressure Table

Receipt Point Pressure Tiers

[psig]

Add/(Subtract) from Base (on a $/MMBtu basis)

From	To	Rate
(***)	(***)	(***)
(***)	(***)	(***)
(***)	(***)	(***)
(***)	(***)	(***)
(***)	(***)	(***)
(***)	(***)	(***)

EX-10.5

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Exhibit 10.5

GAS GATHERING AGREEMENT

BETWEEN

COWTOWN PIPELINE PARTNERS L.P. ("GATHERER")

AND

BLUESTONE NATURAL RESOURCES II, LLC ("PRODUCER")

Lake Arlington Gathering System, Tarrant County, Texas

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TABLE OF CONTENTS

1. Definitions    1

2. Dedication    6

3. Reservations of Parties    7

4. Receipt Point(s) and Delivery Point(s)    7

5. System Operations; Imbalances    9

6. Quantity; Nominations and Dispatching    10

7. Quality    11

8. Tests    13

9. Measurement and Meter Testing    13

10. Allocation of Gains, Fuel and Loss    16

11. Fees    16

12. Accounting, Payments and Credit Assurances    17

13. Warranty    19

14. Taxes    20

15. Indemnity    20

16. Force Majeure    22

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17. Unprofitable Operations and Rights of Termination    23

18. Term    23

19. Regulatory Bodies    24

20. Disputes    24

21. Notices and Payments    24

22. Right to Process the Subject Gas    26

23. Assignment    26

24. Miscellaneous    26

25. Gas Gathering at Village Creek Pad    27

EXHIBIT A: CONTRACT AREA

EXHIBIT B: RECEIPT POINTS AND DELIVERY POINTS

EXHIBIT C: THIRD PARTY RECEIPT AND DELIVERY POINTS

EXHIBIT D: EXCLUDED SHUT-IN WELLS

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GAS GATHERING AGREEMENT

THIS GAS GATHERING AGREEMENT (the "Agreement") is made and entered into as of the Effective Date by and among COWTOWN PIPELINE PARTNERS L.P., a Texas limited partnership ("Gatherer"), and BLUESTONE NATURAL RESOURCES II, LLC ("Producer"), a Delaware limited liability company. Gatherer and Producer are sometimes individually referred to herein as a "Party" and collectively as the "Parties."

WITNESSETH, THAT:

WHEREAS, Producer is in the business of producing gas and owns gas production from one or more wells on the lands within the Contract Area (or lands pooled therewith) and desires for Gatherer to gather such gas for redelivery to Producer or Producer's Transporter;

WHEREAS, Gatherer is in the business of providing natural gas gathering services along its Gathering System and desires to receive, gather and deliver such gas to Producer or Producer's Transporter, subject to the terms and conditions herein; and

NOW, THEREFORE, for good and valuable consideration the adequacy, receipt and sufficiency of which are hereby set forth and acknowledged, and for all of the representations, warranties and mutual covenants set forth herein, Gatherer and Producer agree as follows:

1.Definitions

1.1. For the purpose of this Agreement, the following terms and expressions used herein are defined as follows:

a.“Affiliate” shall mean, with respect to any specified Person, any other Person that directly or indirectly, through one or more intermediaries, Controls, is Controlled by, or is under common Control with, such specified Person. As used in this definition, the term “Control” (including its derivatives and similar terms) means the ownership, directly or indirectly, of fifty percent (50%) or more of the capital stock issued by a corporation, the limited liability company interests of a limited liability company or the equivalent equity interests in any other Person, the holders of which are ordinarily, in the absence of contingencies, entitled to vote for the election of directors (or Persons with management authority performing similar functions) of such Person, even though the right so to vote has been suspended by the happening of such a contingency. Gatherer acknowledges and agrees that Producer’s majority owner is a private equity sponsor that owns and controls a number of other portfolio companies engaged in the oil and gas business

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and that none of such other portfolio companies shall be considered an “Affiliate” under this Agreement if neither Producer nor any personnel of Producer directly or indirectly direct or cause the direction of the management and policies of that company. Producer acknowledges and agrees that Gatherer is controlled by First Reserve Corporation, which owns and controls a number of other portfolio companies engaged in the oil and gas business and none of such other portfolio companies shall be considered an "Affiliate" under this Agreement if Gatherer nor any personnel of Gatherer directly or indirectly direct or cause the direction of the management and policies of that company.

b."Asset Purchase Agreement" shall mean that certain Asset Purchase Agreement by and among QRI, Cowtown Gas Processing L.P. and Cowtown Pipeline L.P. and Producer, dated January 22, 2016.

c."Btu" shall mean one British thermal unit, which is the quantity of heat required to raise one pound avoirdupois of pure water from 58.5 degrees Fahrenheit to 59.5 degrees Fahrenheit at a constant pressure of 14.73 pounds per square inch absolute.

d."Component" shall mean those hydrocarbon and non- hydrocarbon molecular constituents which are definable by industry standards and procedures. Such Components as used in this Agreement
shall be:

N2 - Nitrogen

CO2 - Carbon Dioxide

H2S - Hydrogen Sulfide

C1 - Methane

C2 - Ethane

C3 - Propane

iC4 - Iso-butane

nC4 - Normal Butane

iC5 - Iso-pentane

nC5 - Normal Pentane

C6+ - Hexanes and Heavier Compounds

e."Contract Area" shall mean that area as described or outlined on Exhibit A which is attached hereto and made a part hereof for all purposes, but specifically excludes Producer’s and/or its Affiliates’ leasehold interests owned immediately prior to the Effective Date within the Contract Area but not listed on Exhibit A.

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f."CPI Adjustment" shall mean that percentage equal to the
percentage increase between:

(i) the seasonally unadjusted consumer Price Index for Urban Wage Earners and Clerical Workers (all items), U.S. city Average (1982-84 =100), as published by the U.S. Department of Labor, Bureau of Labor Statistics ("CPI-W") for the month of December of the second year prior to the Escalation Date; and

(ii) the seasonally unadjusted CPI-W for the month of December immediately preceding the Escalation Date.

g.“Crestwood Offload Point” shall mean the interconnect between Third Party Gatherer's central delivery point and Gatherer’s Gathering System, as described on Exhibit C. With regard to the Subject Gas produced from the Village Creek Pad, the Crestwood Offload Point is not and will not be deemed to be a Receipt Point on Gatherer's Gathering System.

h."Day" shall mean a period of twenty-four (24) consecutive hours beginning and ending at seven o'clock a.m. Central Standard Time.

i."Dedicated Properties" shall mean (i) Producer’s and/or its Affiliates’ leasehold interest as of the Effective Date within the Contract Area in and to those certain oil, gas and/or mineral leases, as are listed on Exhibit A, and (ii) Producer’s and/or its Affiliates’ interests within the Contract Area in and to any new oil, gas and/or mineral lease acquired by Producer or its Affiliates after the Effective Date, provided that any wells on lands covered by such lease or lands pooled therewith and within the Contract Area are connected to the Gathering System pursuant to Section 4.4.

j."Delivery Points" shall mean the point(s) of interconnect between the Gathering System and the Transporter receiving the Gas, which point(s) are shown on Exhibit B which is attached hereto and made a part hereof for all purposes.

k.“Effective Date” shall have the meaning set forth in Section 1(c) of the Letter Agreement.

l."Electrical Power" shall mean the electricity consumed in the operation of, and purchased from a utility or like entity which serves, the Gathering System and any of the related field facilities.

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m."Escalation Date" shall mean January 1, 2018 and each January 1^st thereafter during the Term.

n."Fuel and Loss" shall mean the gas volumes used or consumed in the operation of the Gathering System, which shall include, but shall in no way be limited to, (i) fuel used for dehydration, compression, conditioning, blending, treating, or recompression, (ii) gas needed for line pack, (iii) gas vented during operations, (iv) lost and unaccounted for gas, and (v) any Liquefiable Hydrocarbons that become separated from the gas while the gas is in the Gathering System.

o."Gas" shall mean natural gas which is owned or controlled by Producer and producible from wells drilled on Dedicated Properties or lands pooled therewith within the Contract Area, including casinghead gas produced with crude oil, gas from gas wells produced in association with crude oil (associated gas), and gas from condensate wells (non-associated gas), and shall include any inerts or impurities contained therein.

p.“Gathering Fee” shall have the meaning set forth in Section 11.1.

q."Gathering System" shall mean, but shall in no way be limited to, the gas gathering pipelines, fuel gas pipelines, dehydration facilities, compression facilities, junctions, heaters, meters, separators, electric power lines, communications cables, roads, and other related facilities and equipment, including the rights to the lands located thereon, necessary to gather and transport gas from the Gathering System's Receipt Point(s) to the Delivery Point(s), from the inlet flange of the pipeline metering facility installed at the Receipt Point(s) up to the upstream flange of the metering facility at the Delivery Point(s), and shall include any expansion of the Gathering System as provided in Section 4.4.

r.“GPM” shall mean gallons per thousand cubic feet.

s.“Letter Agreement” means that certain letter agreement executed by the Parties contemporaneously with this Agreement.

t.“Lift Gas” shall mean the Gas, reserved by Producer under Section 3.2, used by Producer for gas lift operations in the Contract Area, measured in MCFs at meter station number TXSA 119MU Arlington Plant MU.

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u."Liquefiable Hydrocarbons" shall mean ethane, propane, iso-butanes, normal butanes, iso-pentanes, normal pentanes, hexanes and heavier hydrocarbons, and incidental methane, or any mixtures thereof, which may be recovered or extracted in the Gathering System.

v."MCF" shall mean 1,000 standard cubic feet of gas.

w."MMBtu" shall mean 1,000,000 Btu's.

x."MMCF" shall mean 1,000,000 standard cubic feet of gas.

y."MMCFD" shall mean 1,000,000 standard cubic feet of gas per day.

z."Month," "billing month," "period," and "accounting period" shall mean the period beginning at seven o'clock a.m. on the first day of a calendar month and ending at seven o'clock a.m. on the first day of the next succeeding calendar month.

aa."Person" means any natural person, corporation, limited liability company, partnership, joint venture, association, cooperative, or other entity.

ab. "psia" shall mean pounds per square inch absolute.

ac. "psig" shall mean pounds per square inch gauge.

ad."Receipt Points" shall mean the inlet flange of Gatherer's metering facilities located at or near each of Producer's wells located within the Contract Area or such other point as may be mutually agreed upon by the Parties. The Gathering System's Receipt Point(s) are listed on Exhibit B to this Agreement which is attached hereto and made a part hereof for all purposes and which may be amended from time to time to reflect the addition or deletion of a Receipt Point.

ae."SCF" or "standard cubic foot of gas" shall mean the amount of Gas necessary to fill a cubic foot of space when the Gas is at a pressure of 14.65 pounds per square inch absolute and a temperature of 60 degrees Fahrenheit.

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af.“Senior Executives” shall have the meaning set forth in Section 20.1.

ag.“Subject Gas” means the Gas other than natural gas owned by Tokyo Gas and subject to the Tokyo Gas Gathering Agreement.

ah."Term" shall have the meaning set forth in Section 18.

ai.“Third Party Delivery Points” shall mean the points of interconnect between the Third Party Gathering System and a Transporter, which points are described on Exhibit C.

aj.“Third Party Gatherer” shall mean Access Midstream Partner LP.

ak.“Third Party Gatherer’s Gathering System” shall mean the gathering system owned and operated by Third Party Gatherer.

al.“Third Party Gathering System Fuel” shall mean that gas or electricity consumed or used in the operation of the Third Party Gatherer's Gathering System, which includes gas consumed or used in gathering and compressing, or treating gas on the Third Party Gatherer's Gathering System, but shall not include lost and unaccounted for gas, or gas vented during operations.

am.“Tokyo Gas” shall mean Tokyo Gas, Co., Ltd.

an.“Tokyo Gas Gathering Agreement” shall mean that certain Amended and Restated Gas Gathering Agreement, dated as of September 1, 2008, among Gatherer, Quicksilver Resources Inc. and Tokyo Gas, as amended, modified or otherwise supplemented.

ao."Total Delivered Quantities" shall have the meaning set forth in Section 10.1.

ap."Transporter" shall mean the receiving pipeline(s) downstream of the Gathering System into which the Subject Gas gathered hereunder is to be delivered at the Delivery Point(s).

aq.“Village Creek Gas Lift Facility” shall have the meaning set forth in Section 25.5.

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ar.“Village Creek Lift Gas” shall have the meaning set forth in Section 25.5.

as.“Village Creek Pad” shall mean Producer’s wells located on the pad depicted on Exhibit A as further described in Section 25.5.

at.“Village Creek Pad Receipt Point” shall mean Third Party Gatherer's meter on the Village Creek Pad, as further described in Section 25.2 and on Exhibit C.

au.“Village Creek Pad Volume” shall have the meaning set forth in Section 25.4.

2.
Dedication

2.1.Subject to the terms and provisions hereof, Producer (a) dedicates the Dedicated Properties to the Gathering System for gathering by Gatherer and (b) commits to deliver or cause to be delivered at Gatherer’s Receipt Point(s) the total volume of Subject Gas from wells now or hereafter drilled on the lands covered by the Dedicated Properties (or lands pooled therewith), in each case excluding the Subject Gas reserved or utilized by Producer in accordance with the terms of Section 3. Any transfer by Producer of its right, title, or interest in the Dedicated Properties or in the Subject Gas owned by Producer, or in an oil and gas lease, fee mineral interest or other agreement, interest or right which creates or gives rise to Producer’s interest in the Subject Gas owned by Producer, to a third party, whether by farmout, contract, or otherwise, shall be subject to this Agreement. In addition, Producer will notify any person to whom Producer transfers all or a portion of its right, title, or interest in or out of the Dedicated Properties or the Subject Gas owned by Producer that such Dedicated Properties, and the Subject Gas owned by Producer located under the lands covered by such Dedicated Properties is dedicated pursuant to the terms of this Agreement to be gathered by Gatherer. Producer will notify Gatherer of any such transfer within 10 days of the effective date. Failure of Producer to comply with the foregoing shall not affect Gatherer’s rights herein or the dedication being binding on successors or assignees.

2.2.Gas shall be delivered to the Receipt Point(s) after standard mechanical separation by Producer for the removal of free water and free liquid hydrocarbons, but shall not otherwise be processed by Producer for the removal of Liquefiable Hydrocarbons.

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2.3.    Gatherer agrees that subject to the provisions hereof, it will receive the Subject Gas from the Receipt Point(s), and will cause the redelivery of such Subject Gas, less Producer’s pro rata share of Fuel and Loss, to Producer or Producer's Transporter at the Delivery Point(s).

2.4.    To the extent Producer acquires any additional leasehold interests within the Contract Area that are subject to an existing services contract with Gatherer, such interests shall remain subject to such contract until the expiration or termination of such contract unless Producer and Gatherer mutually agree to a release under the terms of such contract and dedicate and commit the interests to this Agreement. To the extent Producer acquires any additional leasehold interests within the Contract Area that are subject to an existing dedication, such interests shall not be subject to this Agreement for so long as the prior dedication remains in effect without Producer exercising any extension rights or entering into an agreement to extend the duration of the prior dedication.

2.5.    Producer hereby represents and warrants to Gatherer, the following: (i) Exhibit A contains true, accurate, and complete descriptions of all oil, gas and/or mineral leases within the Contract Area acquired from QRI pursuant to the terms to Asset Purchase Agreement and owned by Producer or its Affiliates as of the Effective Date, which are dedicated and committed to the Gathering System as of the Effective Date; and (ii) Producer or its Affiliates have the right to dedicate and commit such oil, gas and/or minerals leases to the Gathering System. To the extent that Producer did acquire from QRI pursuant to the Asset Purchase Agreement oil, gas and/or mineral leases within the Contract Area which have been omitted from Exhibit A, such oil, gas and/or mineral leases shall be deemed to be included on Exhibit A and the Parties shall promptly amend Exhibit A to add such omitted oil, gas and/or mineral leases. Such amendments to Exhibit A shall be Gatherer’s sole and exclusive remedy for Producer’s breach of any representation or warranty in this Section 2.5.

2.6    Either Party may record a mutually agreeable form of memorandum of this Agreement in the official public records of the counties located within the Contract Area.

3.
Reservations of Parties

3.1.Producer reserves all liquid hydrocarbons, oil, or condensate removed by Producer by means of mechanical gas-liquid separators (including heater-

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treaters), drips, and/or lines from the Gas prior to delivery to Gatherer. If mechanical cooling is performed by Producer to meet the temperature specifications of this Agreement, Producer shall not reduce the temperature of the Gas below 60 degrees Fahrenheit.

3.2.Producer reserves all Gas that may be required for cycling, repressuring, pressure maintenance, and gas lift operations with respect to gas reservoirs on the premises committed hereunder; provided, however, that the Gas used in such operations shall be subject to the terms of this Agreement (to the extent that such Gas can be economically saved) and delivered to Gatherer following the cessation of such operations.

3.3.Producer reserves that amount of Gas which is required for above ground development and operation within the Contract Area.

3.4.Producer expressly reserves the right to deliver or furnish to Producer's lessor such Gas as required to satisfy the terms of Producer's oil and gas leases.

4.
Receipt Point(s) and Delivery Point(s)

4.1.Producer shall be responsible for all arrangements and, at its own expense, shall construct, equip, maintain, and operate all facilities (including, but not limited to, all necessary separation, dehydration, and/or compression equipment), necessary to deliver the Gas to Gatherer at the Receipt Point(s) at such pressure as is required and sufficient to enter the Gathering System, but not to exceed 1,200 psig.

4.2.Subject to the then current operating conditions on the Gathering System, outages or restrictions due to maintenance or force majeure, or any interruption permitted under this Agreement, Gatherer will use commercially reasonable efforts to operate its central compression facility(ies) existing as of the Effective Date to maximize volumes across its Gathering System. If, in addition to the foregoing, Gatherer has available compression capacity, it will use commercially reasonable efforts to provide optimal Receipt Point(s) pressure service to Producer, including in response to any written request(s) made by Producer to Gatherer, and other third parties on the Gathering System on a not unduly discriminatory basis. In the event Gatherer desires to remove any compression unit(s) existing as of the Effective Date before the tenth anniversary of the Effective Date, Gatherer shall obtain Producer’s consent, which consent shall not to be unreasonably delayed or withheld, before removing such compression unit(s). For the avoidance of doubt, Gatherer acknowledges and agrees that it shall not be unreasonable if Producer

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withholds consent because it would adversely impact current operations, or if Producer conditions its consent on the requirement that Gatherer add back compression in the future if Producer’s drilling or development plans so require.

4.3.Subject to Sections 4.1 and 5.1, at any time during the term of this Agreement, Producer may request that the Parties enter into negotiations to add compression to the Gathering System to reduce or maintain the pressure at which Producer must enter the Gathering System and to determine the mutually agreeable commercial terms and conditions under which Gatherer would install and operate such additional compression, and Gatherer and Producer agree to participate fully and reasonably in such negotiations.

4.4.Gatherer, at Producer's expense, shall (i) install, construct and equip all meters and facilities necessary to measure the Gas at the Receipt Point(s) and (ii) secure any right-of-way, easements, and permits as are necessary and appropriate to construct, operate, maintain and access such facilities. Gatherer, at its own expense, shall thereafter maintain and operate such facilities throughout the Term of this Agreement.

4.5.If Producer acquires additional mineral interests or oil, gas and/or mineral leases within the Contract Area, Producer shall notify Gatherer with any proposed reasonable supporting documentation (including the location of any existing or proposed well(s)) sufficient for Gatherer to evaluate whether building an expansion of the Gathering System to any existing or proposed well on such new mineral or leasehold interests would be economic pursuant to the fee structure set forth in this Agreement. Gatherer, in its sole and absolute discretion, may decline to construct any Gathering System expansion to connect the Gathering System to any wells located on lands covered by such new mineral or leasehold interests or lands pooled therewith. Within sixty (60) Days after receiving notice (or, if later, reasonable supporting documentation) from Producer, Gatherer may either elect to construct the expansion pursuant to the fee structure set forth in this Agreement or propose an alternative fee structure that Gatherer deems economic. If Gatherer elects to construct the expansion pursuant to the fee structure set forth in this Agreement, Gatherer shall complete such expansion and be ready to accept Subject Gas as follows: (a) for an expansion requiring two (2) or fewer miles to connect the well(s) to the Gathering System, no later than one hundred and twenty (120) days; and (b) for all other expansions, as soon as reasonably practicable using diligent efforts; provided that the foregoing time periods in (a) and (b) shall be extended day-for-day for the duration of any events of force majeure affecting Gatherer’s performance, after receiving notice (or, if later, reasonable supporting

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documentation) from Producer. In the event such expansion is not completed and accepting Subject Gas within such time period, the affected new mineral or leasehold interest and land pooled therewith (but excluding any Dedicated Properties already connected to Gatherer’s System) shall, at Producer’s election by written notice to Gatherer delivered within five (5) days following such period of time, no longer be Dedicated Properties hereunder or subject to this Agreement in any manner whatsoever. If Gatherer proposes an alternative fee structure, then Producer may elect in its sole and absolute discretion to either (i) construct the connection to the Gathering System at Producer’s sole cost and expense, (ii) amend this Agreement to provide for the alternative fee structure proposed by Gatherer, in which case Gatherer shall construct the connection; or (iii) not connect such leasehold interests the Gathering System. If Gatherer elects to not connect, then the new mineral or leasehold interest and land pooled therewith (but excluding any Dedicated Properties already connected to Gatherer’s System) shall no longer be Dedicated Properties hereunder or subject to this Agreement in any manner whatsoever. If Producer elects to build the connection itself, such Gathering System expansion must meet all of Gatherer's specifications, and Gatherer will be responsible for the meter station and connection to the existing Gathering System. Gatherer may, at its election, but only within two years (2) of the initial delivery of production from the connection to the Gathering System, acquire the ownership of the connecting facilities installed by Producer by reimbursing Producer for the actual cost with no allowance for inflation or depreciation. In such event, Producer agrees to execute all assignments or contracts deemed reasonably necessary to accomplish the transfer to Gatherer of title to the Gathering System expansion, including rights-of-way and easements, on an “as is, where is” basis and with other terms and conditions customary for the purchase and sale of midstream assets within the Contract Area.

4.6.Gatherer hereby agrees to deliver the Subject Gas to Producer or Producer's nominated Transporter, less Producer's pro rata share of Fuel and Loss, at the Delivery Point(s). The Subject Gas shall be deemed to have been delivered to Producer or to the Transporter on Producer’s behalf at the Delivery Point(s), and to have passed through the Delivery Point(s), when the Subject Gas passes through the upstream flange of the metering facility at the Delivery Point(s).

5.
System Operations; Imbalances

5.1. Gatherer shall retain full operational control of the Gathering System and shall at all times be entitled to schedule deliveries and to operate its facilities in a manner consistent with safe and prudent operating practices under the conditions which may exist from time to time. Accordingly, Gatherer may interrupt

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the gathering of the Subject Gas as necessary to test, alter, modify, enlarge, expand, maintain or repair any facility or property comprising any part of or appurtenant to the Gathering System; provided, however, during the time period during such interruption, Producer may dispose of the Subject Gas as it see fit and, if such interruption continues for a period of one hundred twenty (120) consecutive days, extended day-for-day for the duration of any events of force majeure, Producer shall have the option, exercised solely at its discretion, to permanently release the Subject Gas produced from the affected well(s) by providing to Gatherer thirty (30) days' advance written notice, other than to the extent that prior to the expiration of such notice interruptions have ceased. It is understood and agreed by the Parties that in order for Gatherer to maintain efficiency in the Gathering System, it will be necessary to maintain a uniform rate of flow of the Gas to the Gathering System from all sources during each twenty-four (24) hour period. Therefore, Producer agrees that it will cooperate with Gatherer in regulating the flow rate of the Gas and in establishing a producing schedule to deliver on a commercially reasonable basis the Gas at a uniform and continuous flow rate. In the event that Gatherer enters into an operational balancing agreement with Producer's Transporter, Producer hereby agrees to be bound by the terms set forth therein.

5.2.It is acknowledged that, because of dispatching and other causes, certain imbalances may occur between the MMBtu's of the Subject Gas delivered hereunder by Gatherer to or for the account of Producer at the Delivery Point(s) and the MMBtu's of the Subject Gas received from or on behalf of Producer at the Receipt Point(s). Such imbalances, if any, shall be eliminated as soon as practical after each such occurrence; provided, however, Gatherer shall not be required to eliminate any imbalance during any month in which the value of the Subject Gas received or delivered, as reasonably determined by Gatherer, is not representative of the market value of natural gas when the imbalance occurred. Any imbalance remaining following the termination of this Agreement shall be eliminated during the Month following the Month in which termination occurs or as soon as practicable thereafter. Producer authorizes the operator of each of Producer’s wells to be its agent for the purpose of providing Gatherer with instructions to adjust allocations of the Subject Gas attributable to that well for gas balancing purposes. Producer represents that it has the right to make any such adjustments and that such adjustments are correct. Gatherer may adjust the Subject Gas allocated to that well in accordance with these instructions but Gatherer is not obligated to do so at any time. Gatherer shall notify Producer of any such allocation change implemented by Gatherer at Producer's operator's instructions.

5.3.The Parties acknowledge that the Gathering System is connected to the facilities of Transporter and, as a result, Gatherer shall be, from time to time,

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subject to certain requirements imposed by Transporter. Accordingly, Gatherer shall have the right under this Agreement to require Producer to comply with the pipeline requirements of Transporter. PRODUCER AGREES TO INDEMNIFY, DEFEND, AND HOLD GATHERER HARMLESS FROM PRODUCER'S FAILURE TO COMPLY WITH TRANSPORTER'S REQUIREMENTS.

6.
Quantity; Nominations and Dispatching

6.1.The Parties acknowledge and agree that natural gas (including Gas) which is owned by Tokyo Gas is subject to the Tokyo Gas Gathering and Processing Agreement and may be delivered to Gatherer by Producer pursuant to a joint operating agreement between Producer and Tokyo Gas.

6.2.Subject to Gathering System capacity, Gatherer shall gather that volume of the Subject Gas legally allowed to be produced which is attributable to the interest owned or controlled by Producer in wells drilled on lands within the Contract Area or lands pooled therewith; provided, Producer or Producer's Transporter or nominee will accept the Subject Gas redelivered on Producer's behalf at the Delivery Point(s). Gatherer may, from time to time, find it necessary to shut off entirely or restrict the flow of gas to the Gathering System notwithstanding anything herein to the contrary and, in such event, Gatherer shall not be liable to Producer for the resulting effect thereof;provided, however, during the time period during such shut off or restriction, Producer may dispose of the Subject Gas as it see fit and, if such shut off or restriction continues for a period of ninety (90) consecutive days, extended day-for-day for the duration of events of force majeure affecting Gatherer’s performance, then the Subject Gas produced from the affected well(s) shall, at Producer’s election by no less than thirty days’ prior written notice to Gatherer, no longer be Dedicated Properties hereunder or subject to this Agreement in any manner whatsoever unless Gatherer has remedied the cause of such shut off or restriction prior to the date set forth in Producer’s notice. Gatherer shall provide Producer reasonable prior notice of any shut down due to routine maintenance and shall prudently work to minimize the amount of such downtime.

6.3.Producer shall make all nominations to Transporter in accordance with Transporter's nomination procedures, and shall make any and all other arrangements necessary for Transporter to receive the Subject Gas at the Delivery Point(s). Producer shall nominate to Gatherer in writing, not less than three (3) business Days prior to the first day of each Month during the term of the Agreement, the daily quantity of the Subject Gas and Gas owned by Tokyo Gas (expressed in MCF's and MMBtu's) that Producer shall deliver to Gatherer at the Receipt Point(s) for gathering during such Month and that Producer or Producer's Transporter

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or nominee shall accept at the Delivery Point(s). The Parties acknowledge and agree that the Gas owned by Tokyo Gas shall be delivered to Gatherer by Producer, but shall be gathered by Gatherer pursuant to the Tokyo Gas Gathering Agreement. As between Producer and Gatherer, Producer shall be solely responsible for imbalances, penalties, cash-out payments, or other consequences of any failure to submit timely and proper nominations in accordance with the requirements of the Transporter or the failure to deliver or receive quantities of the Subject Gas in accordance with said nominations.

6.3.Gatherer and Producer shall designate a dispatcher(s) who shall be continuously on call for nomination purposes, and shall notify each other in writing of such dispatcher(s) and their telephone number(s).

6.4.Producer's dispatcher shall notify Gatherer's dispatcher(s) in advance of any anticipated decrease in delivery rate below the daily nominated quantity. Producer's dispatcher(s) must obtain the prior written approval from Gatherer's dispatcher(s) for any delivery rate in excess of the daily quantity rate. Gatherer's dispatcher(s) shall notify Producer's dispatcher(s) of any anticipated inability to receive the Gas at a delivery rate less than (a) the daily nominated quantity rate; or (b) a previously orally authorized delivery rate in excess of the daily nominated quantity rate.

6.5.The quantity of Gas delivered by Producer at each Receipt Point hereunder during a Month shall be determined in accordance with the allocation procedures set forth in Section 10 below.

6.6.Producer and Gatherer shall conduct semi-annual technical meetings at which Producer shall provide Gatherer with estimated monthly volume forecasts, drilling and development plans for the next twelve (12) months, and discuss other operational matters, and at which Gatherer shall provide Producer Gatherer’s projected maintenance and system outage schedules, Gathering System pressures and operating constraints, and system balances for the next twelve (12) months, and discuss other operational matters.

7.
Quality

7.1.Gatherer shall not be obligated to receive, gather, or redeliver (as the case may be) the Subject Gas delivered by or on behalf of Producer hereunder that fails to meet the quality specifications of (i) the Transporter at any of the Delivery Point(s), or (ii) the following specifications:

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a.    The Subject Gas must be commercial in quality and free from any foreign materials such as dirt, dust, iron particles, crude oil, dark condensate, free water, and other impurities; and substances which may be injurious to pipelines or which may interfere with the gathering, processing, transmission, or commercial utilization of said Subject Gas;

b.    The Subject Gas shall not contain more than seven (7) pounds of water vapor per MMCF;

c.    The Subject Gas delivered hereunder shall not exceed a temperature of one hundred twenty (120) degrees Fahrenheit, nor have a hydrocarbon dewpoint below forty (40) degrees Fahrenheit, at the Receipt Point(s);

d.    The Subject Gas delivered hereunder shall not contain more than:

(i) One-fourth grain of hydrogen sulfide, or five grains of total sulfur, or one grain mercaptan per one hundred (100) cubic feet;

(ii) one part per million by volume of oxygen;

(iii) that percent by volume of carbon dioxide which would result in the failure of the Subject Gas to meet the specifications of any Transporter at any of the Delivery Points, but in no event more than two percent by volume;

(iv) two percent by volume of nitrogen; or

(v) three percent by volume of a combined total of inerts, including, but not limited to, carbon dioxide and nitrogen Components.

e.    

No diluents such as carbon dioxide, air, or nitrogen shall be
added to the Subject Gas;

f.    The Subject Gas shall contain no carbon monoxide, halogens, or unsaturated hydrocarbons, and no more than 0.1 parts per million of hydrogen; and

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g.    The Subject Gas shall have a total heating value of not less than 950 Btu's nor more than 1050 Btu's per cubic foot and 2 GPM ethane and heavier hydrocarbons.

In the event of any conflict as between specifications of a Transporter and those above, the most stringent or restrictive specifications shall be applicable to the Subject Gas proffered under this Agreement. With respect to the “no water” or “hydrocarbons in liquid form” specification, Producer agrees to operate its facilities in a prudent manner so that no water or hydrocarbons in liquid form enters the Gathering System. In the event Gatherer receives liquid water or hydrocarbons from Producer at any Delivery Point, in addition to any adjustments to gas measurement that may be necessary to accurately reflect the quantity of the Subject Gas delivered by Producer to Gatherer at such Delivery Point, Gatherer shall have the right, if such receipts of liquid water or hydrocarbons have not ceased within seven (7) Days after Gatherer’s written notice to Producer, to cease taking deliveries of the Subject gas at such Delivery Point until such time as Producer rectifies the situation.

7.2.If any of the Subject Gas delivered by Producer hereunder should fail to meet the quality specifications set forth in Section 7.1, Gatherer may elect to either (i) accept and gather such Subject Gas, (ii) accept, but treat and/or condition such Subject Gas prior to gathering at an additional cost, or (iii) refuse to accept such Subject Gas. The acceptance of the Subject Gas not meeting the quality specifications set forth in Section 7.1 shall not be deemed a waiver of Gatherer's right to reject such Subject Gas at any later time, and Gatherer shall be entitled, at any time and from time to time, to decline to accept proffered deliveries of the Subject Gas not meeting the quality specifications set forth herein.

7.3.If Gatherer elects to accept but treat and/or condition the nonconforming Subject Gas prior to gathering, Gatherer shall advise Producer of such election and associated fees and costs to be charged by Gatherer. Producer shall then have a maximum of thirty (30) days to advise Gatherer if it will treat and/or condition such non-conforming Subject Gas and the cost associated with such treatment. If Producer does not elect to treat and/or condition such non-conforming Subject Gas or fails to make such election within the specified time period, then Gatherer shall have the right to (i) proceed with gathering such non-conforming Subject Gas and Producer shall pay to Gatherer all associated fees and costs charged by Gatherer in connection with such actions, or (ii) reject and release such non-conforming Subject Gas from the terms of this Agreement.

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7.4.If there is an enactment of, or change in, any law after the Effective Date that, in Gatherer’s reasonable determination, results in a governmental authority requiring Gatherer or Producer to hold or acquire emission allowances or their equivalent related to the carbon dioxide content or emissions or the greenhouse gas content or emissions attributable to Gas and/or the gathering and/or processing of such Gas (collectively, “Producer’s GHG Emissions”), then Gatherer will notify Producer of such enactment of, or change in, such law. Thereafter, Producer shall use commercially reasonable efforts to provide any required emissions allowances or their equivalents to Gatherer in a timely manner. If Producer fails to provide such emission allowances or their equivalents and Gatherer incurs expenses to acquire such allowances or their equivalents in the marketplace, or incurs any out-of-pocket costs or expenses for disposal or treating of carbon dioxide, or otherwise, or if any other additional economic burden is placed on Gatherer in connection with or related to Producer’s GHG Emissions, including but not limited to any tax, assessment, or other cost or expense (collectively, “Emissions Charges”), such Emissions Charges shall be fully the responsibility of Producer. Should Gatherer incur any such Emissions Charges, Producer shall reimburse Gatherer for the same within thirty (30) Days of receipt of an invoice along with reasonable supporting documentation. If carbon dioxide is sold by Gatherer on behalf of Producer, then the proceeds, net of Emissions Charges, taxes, and costs and expenses of such sale, shall be paid to Producer or deducted from amounts owed by Producer pursuant to this Agreement. Notwithstanding the foregoing, should any such enactment of, or change in, law require Gatherer to construct new facilities or to modify any part of the Gathering System or the Plant under this Section 7.4, the Parties shall negotiate in good faith and use commercially reasonable efforts to agree on the most cost effective method of constructing or modifying such facilities

8.
Tests

8.1.Producer and Gatherer do hereby agree as follows:

a.    Gatherer shall procure or cause to be procured a sample of the Subject Gas at each Receipt Point and Delivery Point, respectively, and analyze the samples by chromatographic analysis to determine the Component content (mole percent), specific gravity, and the Btu content thereof.

b.    Tests provided for in Subparagraphs (a) of this Section 8.1 shall be made by Gatherer using its own equipment or by an independent testing service. Samples will be taken at each Gathering System Delivery Point

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according to the monthly average daily flow capabilities of such Gathering System Delivery Point as follows: Gathering System Delivery Point(s) that average 5,000 Mcf per day and higher shall be sampled monthly; Gathering System Delivery Points that average between 4,999 Mcf and 1,000 Mcf per day shall be sampled quarterly; and Gathering System Points of Delivery that average below 1,000 Mcf per day shall be tested semi-annually or more often as Gatherer deems necessary. All such tests shall be made in accordance with approved engineering practices. Representatives of Producer shall be entitled to witness such tests, and Producer shall give advance written notice to Gatherer in the event that it exercises such right.

8.2.Physical constants required for making calculations hereunder shall
be taken from the Gas Processors Association Physical Constants Publication No. 2145-03 (as amended from time to time). Physical constants for the hexanes and heavier hydrocarbons portion of hydrocarbon mixtures shall be assumed tobe the same as the physical constants for hexane. The heat content per gallon of each liquid hydrocarbon Component shall be determined by multiplying the cubic feet per gallon of such liquid hydrocarbon Component by the heat content per cubic foot thereof.

9.
Measurement and Meter Testing

9.1.The unit of volume for measurement of Gas delivered hereunder shall be one thousand (1,000) cubic feet of Gas (or MCF) at a base temperature of 60 degrees Fahrenheit and at an absolute pressure of 14.65 psia and saturated with water vapor. All fundamental constants, observations, records, and procedures involved in determining the quantity of Gas delivered hereunder shall be in accordance with the standards prescribed in Report Nos. 3 and 8, of the American Gas Association, as amended or supplemented from time to time, respectively. It is agreed that for the purpose of measurement and computations hereunder, the atmospheric pressure shall be assumed to be 14.65 psia regardless of the atmospheric pressure at which the Gas is measured and that the Gas obeys the Ideal Gas Laws as to variations of volume with pressure and specific gravity, including the deviation from Boyle's law, and shall all be made by Gatherer in accordance with applicable rules, regulations, and orders. It is also agreed that Gatherer may apply a uniform correction factor for water vapor if Gatherer deems necessary in its sole and absolute discretion.

9.2.Gatherer shall install, maintain, and operate, or cause to be maintained and operated, a measuring station located at each Receipt Point and Delivery Point. Said measuring station(s) shall be so equipped with orifice meters, recording gauges,

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or other types of meter or meters of standard make and design commonly acceptable in the industry, and of suitable size and design, as to accomplish the accurate measurement of the Subject Gas delivered hereunder. The changing and integration of the charts (if utilized for measurement purposes hereunder) and calibrating and adjusting of meters shall be done by Gatherer. Gatherer shall have the right to utilize electronic gas measuring equipment should it so desire.

9.3.Producer may, at its option and expense, install check meters for checking Gatherer's metering equipment at each Receipt Point; and the same shall be so installed as not to interfere with the operation of the Gathering System.

9.4.The temperature of the Subject Gas flowing through the meter shall be determined by the continuous use of a recording thermometer or device installed by Gatherer, so that it will properly record the temperature of the Subject Gas flowing through the meter.

9.5.The specific gravity of the Subject Gas flowing through the meter shall be determined by methods commonly accepted in the industry. Specific gravities so determined will be used in calculating the Subject Gas deliveries until the next specific gravity test is made.

9.6.Each Party shall have the right to be present at the time of any installation, reading, sampling, cleaning, changing, repair, inspection, testing, calibration, or adjustment done in connection with the other Party's measuring equipment used in measuring deliveries hereunder. The records from such measuring equipment shall remain the property of their owner, but upon request, each will submit to the other its records and charts, together with calculations therefrom subject to return within thirty (30) days after receipt thereof. If meters utilizing charts are used to measure the Subject Gas hereunder, then the charts shall be kept on file for a period of two (2) years, or such longer period as may be required by law. In addition, any other measurement data shall also be kept for the same time period. Each Party, during the first production month, and after that at least semi-annually, or more often if necessary, shall calibrate the meters and instruments installed by it or cause the same to be calibrated. Gatherer shall give Producer ten (10) days notice in advance of such tests so that the latter may, at its election, be present in person or by its representative to observe adjustments, if any are made.

9.7.    If the metering equipment is found to be inaccurate by two percent (2%) or more, registration thereof and any payment based upon such registration shall be corrected at the rate of such inaccuracy for any period of inaccuracy which is definitely known or agreed upon, or if not known or agreed upon, then for a period

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extending back one-half of the time elapsed since the last day of the calibration. Unless conclusively determined that Gatherer's measurement equipment is inaccurate by two percent (2%) or more, Gatherer's measurement shall be deemed to be correct for all purposes hereunder, and no adjustment shall be made to the previous volumes. Following any test, any metering equipment found to be inaccurate to any degree shall be adjusted immediately to measure accurately. If for any reason any meter is out of service or out of repair so that the quantity of the Subject Gas delivered through such meter cannot be ascertained or computed from the readings thereof, the quantity of the Subject Gas so delivered during such period shall be estimated and agreed upon by the Parties hereto upon the basis of the best available data using the first of the following methods which is feasible:

a.    

By using the registration of any check measuring equipment
of Producer, if installed and registering accurately;

b.    

By correcting the error if the percentage of error is
ascertainable by calibration, test, or mathematical calculation; or

c.    

By estimating the quantity of deliveries during preceding

periods under similar conditions when the meter was registering
accurately.

9.8.If Producer shall notify Gatherer, or if Gatherer shall notify Producer, at any time that a special test of any Receipt Point meter is desired, the Parties shall cooperate to secure an immediate verification of the accuracy of such meter and joint observation of any adjustments. All tests of Gatherer's measuring equipment at any Receipt Point shall be made at Gatherer's expense, except that Producer shall bear the expense of tests made at its request if the inaccuracy found is less than two percent (2%). Expense as used in this Section 9.8 shall be limited to actual out-of-pocket costs of Gatherer as the result of testing and shall not include any costs incurred by Producer as the result of witnessing said testing.

9.9.If during any month less than 1,000 MCF of Gas is delivered to a Receipt Point, (except for reasons of Force Majeure), then Gatherer shall charge a meter

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fee applicable to any such Receipt Point equal to (***). Such fee shall be invoiced to Producer and payable thirty (30) days after receipt of such invoice.

9.10.The Parties hereto recognize and acknowledge that technological advances may occur over the term of this Agreement which may render certain measurement devices obsolete, or less accurate, or less efficient than that which may be available. In such event, Gatherer may, with Producer's approval, substitute or utilize such available measurement equipment in lieu of any measurement equipment described above in this Section 9.

9.11.If for any reason the Subject Gas is delivered to Gatherer at a Receipt Point with pulsations that affect the accuracy of the measurement, Producer shall be responsible for installing necessary pulsation dampeners, or other devices, to eliminate or reduce the pulsations to a reasonably acceptable level determined by Gatherer

10.
Allocation of Gains, Fuel and Loss

10.1.Gatherer shall use general industry care in transporting the Subject Gas from the Receipt Point(s) to the Delivery Point(s) for Producer's account or sale. However, the Parties understand and agree that certain volumetric gains and losses in the Subject Gas will occur and shall be shared by and among Producer and other third parties whose gas is transported by Gatherer, in the proportion that the gas of each Person who delivers gas into the Gathering System bears to the total gas received at the respective Receipt Point. In determining the quantity of the Subject Gas delivered by Producer at each Receipt Point hereunder during a Month, Gatherer shall allocate to Producer at each such Receipt Point a quantity of gas equal to (a) a percentage of the total quantities (expressed in MMBtu's) reported for such Month by the Transporter at the Delivery Point(s) (the "Total Delivered Quantities") equal to 100% of such Total Delivered Quantities times a fraction, the numerator of which is the number of MMBtu's of the Subject Gas delivered by Producer during such Month at said Receipt Point, and the denominator of which is the number of MMBtu's of all gas delivered into the Gathering System from all receipt points, minus (b) Producer's applicable Fuel and Loss. In making the determinations under this Section 10, Gatherer may rely on, and shall be fully protected in relying on, any determination, report or statement received by Gatherer from any operator of a well regarding the number of MMBtus delivered from such well into the Gathering System at any receipt point on the Gathering System.

10.2.Producer's pro rata share of such Fuel and Loss shall equal the product of the total Fuel and Loss utilized, consumed or incurred by the Gathering

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System, multiplied by a fraction, the numerator of which is Producer's MMBtu's of the Subject Gas metered into the Gathering System at the Receipt Point(s) and the denominator of which is the total number of MMBtu's of gas metered into the Gathering System upstream of the Receipt Point(s).

10.3.Electrical Power is utilized in the operation of the Gathering System (including Electrical Power used for dehydration, compression, conditioning, blending, treating, or recompression), and Producer's pro rata share shall equal the product of the total dollar amount paid for such Electrical Power multiplied by a fraction, the numerator of which is the number of Producer's MMBtu's of the Subject Gas metered into the Gathering System upstream of the Receipt Point(s) and the denominator of which is the total number of MMBtu's of gas metered into the Gathering System upstream of the Receipt Point(s), to be invoiced to Producer and paid to Gatherer in accordance with Section 12 below. Producer reserves the right to participate in the selection of Electrical Power suppliers but Gatherer is entitled to make the final decisions on such selections.

11.
Fees

11.1.Producer shall pay to Gatherer a rate equal to (***) per MCF of the Subject Gas received by Gatherer and metered at the Receipt Point(s), subject to adjustment as provided in Section 11.3 (such rate, as so adjusted, the "Gathering Fee"). Notwithstanding the foregoing, the Gathering Fee for the Village Creek Pad Volumes shall be (***) per each MCF, subject to adjustment as provided in Section 11.3. In addition to the Gathering Fee, Producer shall pay on each MCF of the Subject Gas received by Gatherer and metered at the Receipt Point(s) an additional rate equal to (***) of the published (***) Index (as published on an MMBtu basis).

11.2.Producer shall pay to Gatherer (***) per MCF of Lift Gas redelivered to Producer pursuant to Lift Gas systems in existence as of the Effective Date, subject to adjustment as provided in Section 11.3 (such rate, as so adjusted, the "Lift Gas Fee").

11.3.On each Escalation Date, the Gathering Fee and the Lift Gas Fee will increase by a percentage equal to the CPI Adjustment.

11.4.Subject to Section 11.5, Gatherer shall have the Exclusive Right to provide Producer's gas lift needs for the remaining Term of the Agreement. As used herein, the term “Exclusive Right" is defined to mean that (i) Gatherer

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shall be the exclusive provider of gas lift services to Producer at the existing and any future points delivered into Producer's existing and future gas lift systems, and (ii) Producer shall negotiate with no other party and deal exclusively with Gatherer to potentially provide any alternative gas lift method which could eliminate or materially alter the then existing manner in which Gatherer supplies lift gas to Producer at existing and future wells. If Gatherer elects (other than as a result of force majeure) to discontinue deliveries of lift gas or fails to provide lift gas at a pressure of 800 psig or higher for a period of thirty (30) consecutive days or longer, Producer shall have the option, exercised solely at its discretion, by providing written notice to Gatherer to terminate Gatherer’s Exclusive Right with respect to the affected points of delivery

11.5.If Producer has Lift Gas needs that require the construction of a new gas lift system within the Contract Area, Producer shall notify Gatherer with any proposed reasonable supporting documentation (including the location of any existing or proposed well(s)) sufficient for Gatherer to evaluate whether building of a new gas lift system to any existing or proposed well would be economic pursuant to the fee structure set forth in this Agreement. Gatherer, in its sole and absolute discretion, may decline to construct any new gas lift system. Within sixty (60) Days after receiving notice (or, if later, reasonable supporting documentation) from Producer, Gatherer shall notify Producer whether or not it elects to construct such new gas lift system pursuant to the fee structure set forth in this Agreement. If Gatherer elects to construct the new gas lift system, such construction shall be completed and functioning as soon as reasonably practicable subject to force majeure affecting Gatherer’s performance, after receiving notice (or, if later, reasonable supporting documentation) from Producer (the “Gas Lift Construction Period”). In the event either Gatherer elects not to construct the new gas lift system or elects to build such construction, but it is not completed and functioning within the Gas Lift Construction Period, Producer shall have the right to cause the proposed Lift Gas needs to be provided as it sees fit, by a third party or otherwise.

11.6.Section 11.4 and Section 11.5 are not intended to hinder Producer from alternative non gas lift methods (including, but not limited to, plungers or other similar lifting technologies) at any individual well (including each such well for which there is no gas lift pipeline connection as of the date hereof), where such lift gas being provided or to be provided, as applicable, by Gatherer is not or will not be adequate at such particular well to provide Producer's lift requirements. Producer shall retain sole discretion in the deployment of these

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alternative non gas lift techniques; provided in the event that Producer employs such artificial non gas lift techniques on a well, it will notify Gatherer within a commercially reasonable time frame.

12.
Accounting, Payments and Credit Assurances

12.1.Producer shall furnish to Gatherer on or before the first day of each month a report or statement disclosing information necessary to enable Gatherer to determine the percentage of gas delivered at each Receipt Point that is owned by Producer and the percentage of gas delivered at each Receipt Point that is owned by any other working interest owner for which Producer delivered gas to the Gathering System (and each such working interest owner’s respective percentage of such gas) related to the preceding month. Gatherer shall furnish to Producer on or before the twenty-fifth (25^th) day of each month a report or statement disclosing information necessary to enable Producer to make reasonable and accurate statistical and accounting entries upon its books concerning all phases of this Agreement related to the preceding month, including any statement of the Subject Gas delivered for Producer's account to its Transporter, the total volume of the Subject Gas in MCF and in MMBtu measured at the Receipt Point(s), Producer's pro rata share of Fuel and Loss and the cost billed to Gatherer for Electrical Power, if any, and the amounts due Gatherer for the services provided hereunder. Producer shall remit the amounts due Gatherer hereunder within thirty (30) days after the receipt of Gatherer's statement. PRODUCER SHALL INDEMNIFY AND HOLD GATHERER HARMLESS FROM ANY AND ALL CHARGES, PENALTIES, COSTS AND EXPENSES OF WHATEVER KIND OR NATURE ARISING FROM PRODUCER'S FAILURE TO PAY SUCH PAYMENTS, INCLUDING COSTS AND EXPENSES OF ANY LITIGATION AND REASONABLE ATTORNEYS' FEES ASSOCIATED THEREWITH. Unpaid amounts due hereunder shall accrue interest at the lesser of a rate equal (***), until the balance is paid in full.

12.2.Each Party shall have the right during reasonable hours to examine books, records, charts, and original test data of the other Party to the extent necessary to verify the accuracy of any statement, charge, credit, computation, test, or delivery made pursuant to any provision hereof. If any such examination reveals any inaccuracy in any such statement, charge, credit, computation, test, or delivery, the necessary adjustment shall be promptly made without interest or penalty. Neither Party will have any right to recoup or recover prior overpayments or under payments that result from error that occur in spite of good faith performance if the amounts involved do not exceed fifty dollars ($50.00) per month per Receipt Point.

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12.3.Producer shall be responsible for the payment of all royalties due on the Gas. Producer shall indemnify and hold Gatherer harmless from any and all claims, actions, causes of action, damages, liability, or obligations arising out of or in any way related to the payment of the lessor's royalty or any other burden or encumbrance affecting the Gas.

12.4.Notwithstanding any change in ownership of Producer's properties, Gatherer shall never be required to make payments or to give notices required under the provisions of this Agreement to more than one party.

12.5.All accounting records and documents directly related to this Agreement prepared by any Party hereto shall be retained for a period of not less than two years following the end of the calendar year of their origination. The Parties further agree that all matters relating to the accounting hereunder for any calendar year shall be considered correct and not subject to further audit or legal challenge after two years following the end of the calendar year.

12.6.Producer creditworthiness requirements shall be substantially similar to those requirements set forth below:

a. Producer will be deemed creditworthy: (i) during a period in which Producer does not have long-term secured debt securities rated by S&P and Moody’s, then if according to the most recent of (y) Producer’s audited annual financial statements, or (z) Producer’s quarterly financial statements, (A) its current ratio (dividing current assets (which shall include available borrowings under its credit facility and undrawn equity committed by its equity holders) by current liabilities) is (***) or higher and (B) its leverage ratio as determined using the methodology required by its bank group is at least (***) below its then-current bank group covenant but in no event greater than (***); or (ii) otherwise, if its long-term unsecured debt securities are rated at least BB- by Standard & Poor's Corporation ("S&P") and at least Ba3 by Moody's Investor Service ("Moody's"); provided, however, that if the Producer's rating is at BB- or Ba3 and the short-term or long-term outlook is negative, Gatherer may require further analysis. Producer shall provide its most recent audited financial statements on the Effective Date and, in the event Producer does not have long-term unsecured debt securities rated by S&P and Moody’s, then Producer must also provide Gatherer audited annual financial statements on an annual basis and unaudited quarterly financial statements on a quarterly basis.

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b.     If Producer does not meet the criteria described above, then Producer may request that Gatherer evaluate its creditworthiness based upon the level of service requested relative to the Producer's current and future ability to meet its obligations. Further, if Producer's creditworthiness does not meet any of the foregoing criteria, Producer will be considered creditworthy if Producer maintains and delivers to Gatherer an irrevocable guaranty of payment in form acceptable to Gatherer, or an irrevocable letter of credit from a financial institution rated at least A- by S&P or at least A3 by Moody's, in a form acceptable to Gatherer, in either case of the guaranty or the letter of credit in an amount satisfactory to Gatherer, which will be equal to the total amounts invoiced to Producer by Gatherer in the immediately preceding two (2) Months. The obligation to maintain such credit assurance shall extend until such time as Producer is deemed creditworthy as defined herein. Producer shall provide the guaranty or the letter of credit within twenty (20) days of written notice by Gatherer that such financial assurance is required.

c. The creditworthiness requirements set forth in this Section 12.6 shall apply to any permitted assignment (in whole or in part), and to any permitted permanent release, as applicable, of this Agreement. Gatherer shall apply consistent evaluation practices to all similarly situated producers to determine Producer's financial ability to perform the payment obligations due to Gatherer.

13.
Warranty

PRODUCER warrants the title to all the Subject Gas owned by Producer and all components thereof which shall be delivered by Producer to Gatherer hereunder, the right to enter into this Agreement with reference to such Subject Gas, and that such Subject Gas owned by Producer is free from all liens and adverse claims; and AGREES, IF NOTIFIED THEREOF BY GATHERER, TO INDEMNIFY, DEFEND AND HOLD GATHERER HARMLESS FROM AND AGAINST ANY AND ALL SUITS, ACTIONS, LOSSES, DEBTS, ACCOUNTS, DAMAGES, COSTS AND EXPENSES ARISING FROM OR OUT OF ANY ADVERSE CLAIM AS TO PRODUCER'S TITLE, INCLUDING BUT NOT LIMITED TO , ANY ADVERSE CLAIMS BROUGHT BY OR THROUGH A MINERAL INTEREST OR ROYALTY OWNER, TO OR AGAINST THE SUBJECT GAS OWNED BY PRODUCER. Producer agrees to make settlement for all royalties, overriding royalty interests, and/or production payments due and payable on the Subject Gas delivered to Gatherer hereunder, any Components of the Subject Gas extracted or saved therefrom, and the sale and disposition of the Subject Gas and any Components thereof, all in accordance with the terms of the leases, interests and/or agreement (including applicable

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instruments of title) from which the Subject Gas delivered to Gatherer hereunder is produced, and all amendments thereto.

Producer also represents and warrants that it has full authority to receive payment for the sum of all of the Subject Gas delivered hereunder.

14.
Taxes

14.1. Producer shall pay or cause to be paid all production, severance and ad valorem taxes, assessments, and other charges levied or assessed against the Gas gathered hereunder, and all taxes and statutory charges levied or assessed against any of Producer's properties, facilities, or operations. Producer shall reimburse Gatherer to the extent of any severance or other such taxes paid by Gatherer on behalf of Producer.

14.2. Gatherer shall pay all taxes and statutory charges levied or assessed against the Gathering System and operations concerning such system.

15.
Indemnity and Damages

15.1.As between the Parties, and as to liability, if any, accruing to either Party hereto or to any third party, Producer shall be solely liable for and in control and possession of, and bear the risk of loss with respect to, the Gas deliverable hereunder until the Gas is delivered to Gatherer at the Receipt Point(s). Gatherer shall be solely liable for and in control and possession of, and bear the risk of loss with respect to, the Gas after the Gas is delivered to Gatherer at the Receipt Point(s) hereunder until the Subject Gas is delivered to Producer or to the Transporter on Producer's behalf at the Delivery Point(s), whereupon Producer shall again be solely liable for the Subject Gas and in control and possession thereof and bear the risk of loss of the Subject Gas delivered to Transporter. If Lift Gas is redelivered to Producer as provided herein, then, in that event, Gatherer shall be solely liable for and in control and possession of such Lift Gas from the time such Lift Gas exits the Gathering System until redelivered to Producer, whereupon Producer shall again be in control and possession and bear the risk of loss of such Lift Gas.

PRODUCER SHALL BE AFFORDED ACCESS TO GATHERER’S PROPERTY AND THE FACILITIES TO THE EXTENT NECESSARY TO CARRY OUT ITS RIGHTS AND OBLIGATIONS UNDER THIS AGREEMENT, AND PRODUCER SHALL FULLY OBSERVE AND COMPLY WITH ALL OF GATHERER’S SAFETY PRACTICES AND PROCEDURES WHILE ON THE PREMISES. PRODUCER HEREBY AGREES TO INDEMNIFY, HOLD

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HARMLESS, PROTECT, DEFEND, AND DISCHARGE GATHERER AND ITS AFFILIATED COMPANIES, PARTNERS, SUCCESSORS, ASSIGNS, OFFICERS, DIRECTORS, MANAGERS, SHAREHOLDERS, MEMBERS, EMPLOYEES AND AGENTS FOR, FROM AND AGAINST ANY AND ALL JUDGMENTS, EXECUTIONS, CAUSES OF ACTION, DEMANDS, RIGHTS, SUITS, DEBTS AND SUMS OF MONEY, ACCOUNTINGS, DUES, PENALTIES, FINES, CLAIMS (INCLUDING, WITHOUT LIMITATION, CLAIMS FOR CONTRIBUTION), LIABILITIES, LOSSES, COSTS, DAMAGES AND EXPENSES (INCLUDING COURT COSTS, REASONABLE COSTS OF INVESTIGATION, DEFENSE AND ATTORNEY’S FEES) FOR THE INJURY TO OR DEATH OF ANY PERSON (INCLUDING, WITHOUT LIMITATION, EACH OF PRODUCER’S AND GATHERER’S EMPLOYEES, AGENTS AND CONTRACTORS) OR PROPERTY DAMAGE OF ANY NATURE, KIND OR DESCRIPTION OR ANY OTHER CLAIM OF ANY NATURE, KIND OR DESCRIPTION BROUGHT BY ANY PERSON, WHETHER LEGAL OR EQUITABLE, WHICH ARISES OUT OF OR RESULTS FROM (I) PRODUCER’S OWNERSHIP AND CONTROL OF (a) THE GAS PRIOR TO THE TIME THAT THE GAS PASSES THROUGH THE GATHERING SYSTEM RECEIPT POINT(S) AND AFTER THE GAS PASSES THROUGH THE DELIVERY POINT(S) AND (b) THE LIFT GAS AFTER THE LIFT GAS HAS BEEN REDELIVERED TO PRODUCER AND PRIOR TO THE TIME THAT GAS, INCLUDING SUCH LIFT GAS, PASSES THROUGH THE RECEIPT POINT, (II) PRODUCER’S OWNERSHIP AND OPERATION (OR ANY OPERATION ON BEHALF OF PRODUCER) OF THE WELLS LOCATED WITHIN THE CONTRACT AREA AND ANY FACILITIES OR EQUIPMENT INSTALLED OR MAINTAINED BY PRODUCER OR ITS OPERATORS UPSTREAM OF THE GATHERING SYSTEM RECEIPT POINT, REGARDLESS OF WHETHER SUCH WAS REQUIRED BY THE TERMS OF THIS AGREEMENT, (III) ANY ACCESS TO GATHERER’S PROPERTY BY (OR ANY DELIVERY OF GATHERER’S RECORDS OR CHARTS TO) PRODUCER OR ITS REPRESENTATIVES, EMPLOYEES, AGENTS OR CONTRACTORS, (IV) PRODUCER’S BREACH OF THIS AGREEMENT, OR (V) ANY VIOLATION OF THE LAW BY PRODUCER, IN EACH CASE REGARDLESS OF ANY SOLE, CONCURRENT OR COMPARATIVE NEGLIGENCE OR STRICT LIABILITY OF GATHERER OR ANY OF THE PERSONS INDEMNIFIED BY PRODUCER UNDER THE FOREGOING PROVISIONS.

GATHERER HEREBY AGREES TO INDEMNIFY, HOLD HARMLESS, PROTECT, DEFEND AND DISCHARGE PRODUCER AND ITS AFFILIATED COMPANIES, PARTNERS, SUCCESSORS, ASSIGNS, OFFICERS, DIRECTORS, SHAREHOLDERS, EMPLOYEES AND AGENTS FOR, FROM

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AND AGAINST ANY AND ALL JUDGMENTS, EXECUTIONS, CAUSES OF ACTION, DEMANDS, RIGHTS, SUITS, DEBTS AND SUMS OF MONEY, ACCOUNTINGS, DUES, PENALTIES, FINES, CLAIMS (INCLUDING, WITHOUT LIMITATION, CLAIMS FOR CONTRIBUTION), LIABILITIES, LOSSES, COSTS, DAMAGES AND EXPENSES (INCLUDING COURT COSTS, REASONABLE COSTS OF INVESTIGATION, DEFENSE AND ATTORNEY’S FEES) FOR THE INJURY TO OR DEATH OF ANY PERSON (INCLUDING, WITHOUT LIMITATION, EACH OF PRODUCER’S AND GATHERER’S EMPLOYEES, AGENTS AND CONTRACTORS) OR PROPERTY DAMAGE OF ANY NATURE, KIND OR DESCRIPTION OR ANY OTHER CLAIM OF ANY NATURE, KIND OR DESCRIPTION BROUGHT BY ANY PERSON, WHETHER LEGAL OR EQUITABLE, WHICH ARISES OUT OF OR RESULTS FROM (I) GATHERER’S CONTROL OF (a) THE GAS AFTER THE GAS PASSES THROUGH THE GATHERING SYSTEM RECEIPT POINTS TO THE TIME THAT THE GAS PASSES THROUGH THE DELIVERY POINT(S) AND (b) THE LIFT GAS FROM THE TIME SUCH LIFT GAS EXITS THE GATHERING SYSTEM UNTIL SUCH LIFT GAS IS REDELIVERED TO PRODUCER, (II) GATHERER’S OWNERSHIP AND OPERATION OF THE GATHERING SYSTEM, (III) GATHERER’S BREACH OF THIS AGREEMENT, OR (IV) ANY VIOLATION OF THE LAW BY GATHERER, IN EACH CASE REGARDLESS OF ANY SOLE, CONCURRENT OR COMPARATIVE NEGLIGENCE OR STRICT LIABILITY OF PRODUCER OR ANY OF THE PERSONS INDEMNIFIED BY GATHERER UNDER THE FOREGOING PROVISIONS. THE INDEMNIFICATION RIGHTS HEREIN SHALL BE CUMULATIVE OF, AND IN ADDITION TO, ANY AND ALL OTHER RIGHTS, REMEDIES OR RECOURSE OF THE PARTIES AND SHALL SURVIVE ANY EXPIRATION OR TERMINATION OF THIS AGREEMENT. TO THE EXTENT AND ONLY TO THE EXTENT THE FOREGOING INDEMNIFICATION RIGHTS ARE BY LAW, EITHER INAPPLICABLE OR NOT ENFORCEABLE, PRODUCER AND GATHERER SHALL EACH BE RESPONSIBLE FOR THE RESULTS OF ITS OWN ACTIONS AND FOR THE ACTIONS OF THOSE PERSONS AND ENTITIES OVER WHICH IT EXERCISES CONTROL.

NOTWITHSTANDING ANYTHING CONTAINED IN THIS SECTION 15 OR ELSEWHERE IN THIS AGREEMENT TO THE CONTRARY, NEITHER PARTY SHALL BE LIABLE FOR ANY PUNITIVE, EXEMPLARY, CONSEQUENTIAL, INCIDENTAL, SPECIAL, OR INDIRECT DAMAGES, LOST PROFITS, OR OTHER BUSINESS INTERRUPTION DAMAGES, IN TORT OR CONTRACT, IN CONNECTION WITH OR OTHERWISE ARISING OUT OF THIS AGREEMENT, EXCEPT TO THE EXTENT SUCH DAMAGES HAVE BEEN AWARDED TO A THIRD PARTY WHO IS NOT AN AFFILIATE OF A PARTY AND ARE SUBJECT

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TO ALLOCATION BETWEEN OR AMONG THE PARTIES PURSUANT TO ANY TERMS OF THIS AGREEMENT.

16.
Force Majeure

In the event any Party is rendered unable, either wholly or in part, by force majeure to carry out its obligations under this Agreement, other than the obligation to make payments due hereunder, it is agreed that on such Party giving notice and full particulars of such inability by telephone and in writing to the other Parties as soon as possible after the occurrence of the cause relied on, then the obligations of the Party giving such notice, so far as they are affected by such force majeure, shall be suspended during the continuance of any inability so caused, but for no longer period, and such cause shall, as far as possible, be remedied with all reasonable dispatch by the Party claiming the force majeure. The term "force majeure" as employed herein shall mean any act or event which wholly or partially prevents or delays the performance of obligations arising under this Agreement if such act or event is not reasonably within the control of and not caused by the fault or negligence of the Party claiming force majeure and which by the exercise of due diligence such Party is unable to prevent or overcome, including, without limitation, by the following enumeration: acts of God; strikes; lockouts; or other industrial disturbances; acts of the public enemy; wars; blockades; insurrections; riots; epidemics; landslides; lightning; earthquakes; fires; storms; floods; washouts; arrests and restraints of governments and people; civil disturbances; explosion, breakage, or accidents to machinery, plant facilities, or lines of pipe; the necessity for making repairs to or alterations of machinery, plant facilities, or lines of pipe; freezing of wells or lines of pipe; partial or entire failure of wells; and the inability of either Producer or Gatherer to acquire, or the delays on the part of either Producer or Gatherer in acquiring, at reasonable cost and after the exercise of reasonable diligence: (a) any servitude, rights-of-way grants, permits, or licenses; (b) any materials or supplies for the construction or maintenance of facilities; and (c) any permits or permissions from any governmental agency if such are required. It is understood and agreed that the settlement of strikes or lockouts shall be entirely within the discretion of the Party having the difficulty and that the above requirements that any force majeure shall be remedied with all reasonable dispatch shall not require the settlement of strikes or lockouts by acceding to the demands of the opposing party when such course is inadvisable in the sole discretion of the Party having the difficulty. Notwithstanding anything contained herein to the contrary, in the event that Gatherer is unable to carry out its obligations under this Agreement due to a force majeure, then during the time period of such force majeure, Producer may dispose of the Subject Gas as it sees fit.

17.
Unprofitable Operations and Rights of Termination

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17.1.If, in the reasonable opinion of Gatherer, (a) the gathering of the Subject Gas from any well within the Contract Area or any Receipt Point(s), or (b) the delivery of the Subject Gas to any Delivery Point(s), is or becomes uneconomical due to its volume, quality, government regulations, or for any other cause, Gatherer shall not be obligated to gather and may cease gathering such Subject Gas so long as such condition exists. Gatherer agrees that in its determination of uneconomical gathering, the same criteria shall be used for the Subject Gas as for all other gas being gathered through the Gathering System. In the event that Gatherer refuses to gather the Subject Gas, Producer may dispose of the Subject Gas not gathered as it sees fit; provided that Gatherer at any time thereafter shall have the right to gather all of the Subject Gas refused, if refused for reason or reasons resulting from an act of Producer or lack of action on the part of Producer, conditioned upon Gatherer giving Producer at least two (2) months’ notice of its election to so do. Notwithstanding anything contained herein to the contrary, in the event that Gatherer refuses to gather the Subject Gas for a period of sixty (60) consecutive days causing Producer’s well(s) to be shut-in, Producer shall have the option, exercised solely at its discretion, to terminate the Agreement in its entirety insofar and only insofar as it pertains to Subject Gas produced from the affected well(s) by providing to Gatherer advance written notice thirty (30) days in advance of such termination.

17.2.Nothing herein shall be construed to require Producer to drill any well or to continue to operate any well which a prudent operator would not in like circumstances drill or continue to operate. Notwithstanding the foregoing, (a) Producer intends to produce the maximum volumes possible and commits to bring all wells currently shut in for economic purposes, other than those set forth on Exhibit D, online as soon as practicable, but in no event later than July 1, 2016 and (b) Producer agrees that it will not shut-in or choke back wells for economic purposes during the calendar years of 2016 through the end of 2018 unless the well reaches the end of its useful life or safety, technical or mechanical reasons necessitate shutting-in or choking back the well.

17.3.It is agreed that Gatherer shall not be obligated to expand the Gathering System in order to provide capacity hereunder.

18.
Term

This terms of this Agreement shall be effective from the Effective Date and, subject to the other provisions hereof, shall continue in full force and effect until the tenth anniversary of the date Producer first delivers Subject Gas to the Receipt Point(s) pursuant to the terms of this Agreement and shall be automatically renewed for one (1)

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year periods thereafter unless on or before one hundred eighty (180) days prior to the expiration of the primary term or the expiration of a one (1) year renewal period a Party provides written notice of termination to the other Party (the “Term”). For the avoidance of doubt, this Agreement shall become effective subject to and simultaneously with the "Closing" as such term is defined under the Asset Purchase Agreement.

19.
Regulatory Bodies

This Agreement and the provisions hereof shall be subject to all valid applicable federal, state, and local laws, order, rules, and regulations. Producer and Gatherer have entered into this Agreement with the understanding, and in reliance on the fact, that this Agreement and/or performance of this Agreement are not and will not be subject to the jurisdiction or regulation of the Federal Energy Regulatory Commission ("FERC"). If this Agreement and/or performance of this Agreement becomes subject to such jurisdiction and/or regulation, this Agreement shall automatically terminate unless Producer and Gatherer agree, in writing, within thirty (30) days of the effective date of the attachment of any such jurisdiction and/or regulation, that this Agreement shall continue after such effective date.

20.
Disputes

20.1. Should a dispute arise between the Parties out of or in connection with this Agreement, the Parties shall promptly seek to resolve any such dispute by negotiations among the senior executives of the Parties who have the authority to settle such dispute ("Senior Executives") prior to the initiation of any lawsuit. The Senior Executives shall meet at a mutually acceptable time and place within fifteen (15) days after such dispute arises and thereafter as often as they reasonably deem necessary to exchange relevant information and to attempt to resolve the dispute. All negotiations and communications pursuant to this Section shall be treated as compromise and settlement negotiations for purposes of the federal and state Rules of Evidence. If the dispute has not been resolved within thirty (30) days after the initial meeting of the Senior Executives, or such longer period as may be mutually agreed upon, either Party may initiate a lawsuit.

20.2. IN ANY SUIT FILED BY A PARTY HERETO TO RESOLVE A DISPUTE ARISING UNDER THIS AGREEMENT OR RELATED TO THE SERVICES PROVIDED HEREUNDER, EACH PARTY HEREBY COVENANTS AND AGREES TO TAKE ALL STEPS NECESSARY TO WAIVE A TRIAL BY JURY.

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21.
Notices and Payments

Any notice, request, demand, statement, or bill provided for in this Agreement shall be in writing and delivered by hand, mail, or email. All such written communications shall be effective upon receipt by the other party at the address of the parties hereto as follow:

Producer

Statements:            BlueStone Natural Resources II, LLC

2100 South Utica

Tulsa, OK 74114

Attn: John Redmond

Email: jredmond@bluestonenr.com

Payments:            BlueStone Natural Resources II, LLC

2100 South Utica

Tulsa, OK 74114

Attn: John Redmond

Email: jredmond@bluestonenr.com

Contractual:            BlueStone Natural Resources II, LLC

2100 South Utica

Tulsa, OK 74114

Attn: John Redmond

Email: jredmond@bluestonenr.com

Gatherer

Statements:            Cowtown Pipeline Partners L.P.

1200 Summit Avenue, Suite 320

Fort Worth, Texas 76102

Attn: Revenue Accounting

Payments:            Cowtown Pipeline Partners L.P.

1200 Summit Avenue, Suite 320

Fort Worth, Texas 76102

Attn: Accounting

Contractual:            Cowtown Pipeline Partners L.P.

700 Louisiana, Suite 2550

Houston, Texas 77002

Attn: VP of Commercial

Email: Darrel.hagerman@crestwoodlp.com

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Any of the Parties may designate a further or different address by giving written notice to the other Parties.

22.
Right to Process the Subject Gas

Producer agrees that Gatherer shall have the right to process, or cause to be processed, blend, or cause to be blended, the Subject Gas delivered hereunder for the extraction of natural gas liquids and other valuable components, to the extent that Gatherer or its Affiliates constructs, acquires or otherwise obtains access to facilities capable of processing such Subject Gas. Upon written notice to Producer that Gatherer is ready and willing to exercise this right, the Parties will negotiate in good faith the terms and fees for the processing of the Subject Gas at any such facility, which terms and fees (i) shall be consistent with those then prevailing in the area for similar processing or blending and (ii) shall be set forth in an amendment to this Agreement or in a supplemental agreement between the Parties.

23.
Assignment

This Agreement shall be binding upon and inure to the benefit of the heirs, executors, administrators, successors, and assigns of the respective Parties hereto, but no transfer of or succession to the interest of any Party hereunder, either wholly or partially, shall affect or bind the other Parties until it shall have been furnished with the original instrument or with the proper proof that the claimant is legally entitled to such interest; provided, however, that in the case of any assignment by Producer (i) such assignment shall be further subject to the satisfaction by Producer’s assignee of the creditworthiness requirements of Section 12.6, and (ii) Producer’s assignee shall be required to expressly agree under such assignment to assume and be bound by all of the obligations of Producer under this Agreement.

24.
Miscellaneous

24.1.No waiver by any Party of any one or more defaults in the performance of any provision of this Agreement shall operate or be construed as a waiver of any other default or future defaults, whether of a like or different character.

24.2.No modification or amendment of the terms and provisions of the Agreement shall be made except by the execution of a written agreement by the

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Parties. This Agreement contains the entire agreement between the Parties and there are no oral promises, agreements, or warranties affecting it.

24.3.The headings in the Agreement are formulated and used for convenience only and shall not be deemed to affect the meaning or construction of any provisions of the Agreement.

24.4.This Agreement supersedes and replaces any other contract(s) or agreements(s) which may exist between the Parties covering the gathering or processing of the Subject Gas owned by Producer dedicated hereunder.

24.5. Nothing in this Agreement is intended to create a partnership or joint venture under state law or to render the Parties hereto jointly and severally liable to any third party. Each of the Parties elects to be excluded from the provisions of Subchapter K, Chapter 1 of Subtitle A, of the Internal Revenue Code of 1986 pursuant to the provisions of Article 761(a) of such code and from any similar provisions of state law. Gatherer shall timely file such evidence of this election as may be required under applicable law.

24.6. Should any section, subsection, paragraph, subparagraph, or other portion of this Agreement be found invalid as a matter of law in a duly authorized court, or by a duly authorized government agency, then only that portion of the Agreement shall be invalid. The remainder of the Agreement which shall not have been found invalid shall remain in full force and effect.

24.7.THIS AGREEMENT, AND ALL QUESTIONS RELATING TO ITS VALIDITY, INTERPRETATION, PERFORMANCE, AND ENFORCEMENT (INCLUDING, WITHOUT LIMITATION, PROVISIONS CONCERNING LIMITATIONS OF ACTIONS) SHALL BE GOVERNED BY AND CONSTRUED IN ACCORDANCE WITH THE LAWS OF THE STATE OF TEXAS, NOTWITHSTANDING ANY CONFLICT-OF-LAWS DOCTRINES OF SUCH STATE OR OTHER JURISDICTION TO THE CONTRARY. ALL MATTERS LITIGATED BY OR BETWEEN THE PARTIES THAT INVOLVE THIS AGREEMENT, THE RELATIONSHIP OF THE PARTIES, OR ANY RELATED DOCUMENTS OR MATTERS HEREUNDER SHALL BE BROUGHT ONLY IN HOUSTON, HARRIS COUNTY, TEXAS.

24.8.This Agreement was prepared jointly by the Parties hereunder and not by any Party to the exclusion of the other. In the event an ambiguity or question of intent or interpretation arises, no presumption or burden of proof will arise favoring or disfavoring any Party by virtue of the authorship, or any greater involvement in the drafting, of any of the provisions of this Agreement.

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24.9.The Parties warrant and represent that no promise, agreement, representation, inducement, or condition which is not herein expressed has been made to either Party by the other, or any agent or representative of either Party to the other, in executing this Agreement. The Parties further warrant and represent they are not relying upon, and expressly disclaim, any such promise, agreement, representation, inducement, or condition which is not herein expressed in executing this Agreement. The Parties represents and warrant they are relying solely upon their own judgment in entering this Agreement.

24.10.This Agreement is being executed contemporaneously with the Parties’ Letter Agreement. The Parties represent, warrant, and agree this Agreement and the Letter Agreement collectively comprise one transaction.

25.
Gas Gathering at Village Creek Pad

25.1Use of Third Party Gatherer. Producer acknowledges and agrees that Gatherer may cause the gathering of the Subject Gas from the Village Creek Pad by Third Party Gatherer at the Village Creek Pad Receipt Point pursuant to a separate gathering agreement between Gatherer and Third Party Gatherer for delivery of such the Subject Gas to a Third Party Delivery Point as follows: On a daily basis, the first 15,000 MMBtus of the Subject Gas produced from the Village Creek Pad will be delivered to the Crestwood Offload Point; the remainder of the Subject Gas produced from the Village Creek Pad may be delivered to any Third Party Delivery Point at the Producer's direction and discretion. In addition, if the total quantity of all gas, inclusive of third party gas, delivered to the Crestwood Offload Point exceeds 15,000 MMBtus per day ("Excess Quantity''), Gatherer shall cause Producer's portion of the Excess Quantity to be delivered to any Third Party Delivery Point, for no additional fee, at the Producer's direction and discretion.

25.2Village Creek Pad Receipt Point. The receipt point for the wells on the Village Creek Pad will be the Third Party Gatherer's meter number 22421 located on the Village Creek Pad.

25.3Quality of the Subject Gas. The quality of the Subject Gas delivered by Producer to the Village Creek Pad Receipt Point shall comply with those specifications and conditions as provided in Section 7 of this Agreement, and specifically Section 7.1, provided in the event of any conflict of quality specifications with downstream transporters, the more stringent or restrictive specifications shall be satisfied. Producer shall be responsible for reimbursing Gatherer for the actual reasonable cost incurred by Third Party Gatherer for the cost of handling and disposal of associated saltwater and other liquids not meeting the applicable

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specifications and conditions as provided above, if Producer delivers such liquids into the Third Party Gathering System. Producer warrants that, with respect to the Subject Gas, it has, to its knowledge, complied with the terms and conditions of this Agreement, and that the Subject Gas to be delivered at the Village Creek Pad will comply with all applicable laws, rules and regulations.

25.4Allocation of Gains, Fuel, Loss and Electrical Power. The following calculations shall be used in lieu of Section 10 to allocate Gain, Fuel, Loss, and Electrical Power to the Village Creek Pad:

a. Gatherer's Allocation of Gain, Fuel, Loss, and Electric Power Incurred on Gatherer's Gathering system (measured in MMBtu's):

The quantity of the Subject Gas attributable to the Village Creek Pad Receipt Point for purposes of allocating Gain, Fuel and Loss on Gatherer's Gathering System shall be calculated as follows: volume of the Subject Gas at Village Creek Pad Receipt Point, less any volume nominated by Producer for delivery to a Third Party Delivery Point other than the Crestwood Offload Point, less any Gain, Fuel, or Loss allocated to Producer on the Third Party Gatherer's Gathering System (the “Village Creek Pad Volume"). This Village Creek Pad Volume shall be multiplied by (i.), (ii.), or (iii.) below to derive the respective allocation for each:

i. Percentage of Gathering System Gain/Loss:

Sum of Total Delivered Quantities, less (the sum of all gas delivered at all Receipt Points, less Gathering System Fuel, less quantities of any Gathering System Gas Lift), divided by the sum of all gas delivered at all Receipt Points;

e.g. a-(b-c-d)

b

ii. Percentage of Gathering System Fuel:

Fuel utilized or consumed by the Gathering System divided by the sum of all gas delivered at all Receipt Points.

iii. Gathering System Electrical Power (in Dollars):

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The total dollar amount paid for such Electrical Power divided by the sum of all gas delivered at all Receipt Points on the Gathering System.

b. Third Party Gatherer Allocation of Gain, Fuel, Loss incurred on Third Party Gatherer's Gathering System (measured in MMBtu's):

i.
When all of the Subject Gas delivered into the Village Creek Pad Receipt Point is nominated for delivery to the Crestwood Offload Point:

1. Allocation of Gathering System Gain/Loss:

Third Party Gatherer's Gain/Loss incurred on the Third Party Gatherer's Gathering System that is attributable to the Subject Gas shall be passed through to the Producer.

2. Percentage of Fuel:

No Third Party Gathering System Fuel shall be passed through or allocated to the Producer.

ii.
When the Subject Gas delivered into the Village Creek Pad Receipt Point is nominated for delivery to other Third Party Delivery Points as well as to the Crestwood Offload Point:

1.
Allocation of Gathering System Gain/Loss:

All Third Party's Gain/Loss incurred on the Third Party Gatherer's Gathering System shall be passed through to the Producer.

2.
Percentage of Fuel:

Fuel incurred on the Third Party Gatherers Gathering System in the delivery of the Subject Gas to Third Party Delivery Points other than the Crestwood Offload Point shall be passed through to the Producer.

38

PORTIONS OF THIS EXHIBIT DENOTED WITH THREE ASTERISKS (***) HAVE BEEN OMITTED PURSUANT TO A REQUEST FOR CONFIDENTIAL TREATMENT

25.5Gas Lift at Village Creek Pad.

a.
In the event that Producer requests Gas for gas lift for:

i.
the following wells (collectively, the “Existing Village Creek Wells”):

(1) Village Creek 8H

(2) Village Creek 10H

(3) Village Creek 12H, or

ii.
any future well situation on the Village Creek Pad,

Gatherer shall promptly install (or cause to be installed) all equipment at the Village Creek Pad necessary to provide gas lift Gas to the wells situated on the Village Creek Pad (collectively, the "Village Creek Gas Lift Facility"), which may include but is not limited to a meter station, over pressure protection valve and device, electronic flow meter, radio communication, SCADA and appurtenant valves and appropriate piping and tubing. Producer agrees to reimburse Gatherer for all actual costs, upon invoice, incurred by Gatherer for the installation of the Village Creek Gas Lift Facility. Following installation, the Village Creek Gas Lift Facility shall become a part of the Third Party Gatherer's Gathering System.

b.
Gatherer will make available (or cause to be made available) to Producer at the Village Creek Gas Lift Facility a quantity of Gas to be used by Producer as field use gas for all present and future wells situated on the Village Creek Pad (as permitted by Section 3.2 of the Agreement). Such field use quantities made available to Producer ("Village Creek Lift Gas") shall be subtracted from the quantities of Gas delivered by Gatherer at the Third Party Delivery Point(s). In the event that the quantities of Village Creek Lift Gas made available to Producer during a given Month exceed the total quantities of Gas delivered for Producer at the Third Party Delivery Point(s) for the given month and the following two (2)

39

PORTIONS OF THIS EXHIBIT DENOTED WITH THREE ASTERISKS (***) HAVE BEEN OMITTED PURSUANT TO A REQUEST FOR CONFIDENTIAL TREATMENT

Months (the ''Un-Replaced Quantities"), then Producer shall purchase upon invoice the Un-Replaced Quantities ($ per MMBtu) at (***), in effect for the Month such Village Creek Lift Gas was delivered by Gatherer or its designee to Producer at the Village Creek Gas Lift Facility. Any amount owed to Gatherer for such Un-Replaced Quantities shall be paid to Gatherer by Producer within thirty (30) days of receipt of invoice from Gatherer.

c.
Notwithstanding any other provision of the Agreement to the contrary (i) no Lift Gas Fee shall apply to the Village Creek Lift Gas and (ii) the Lift Gas Volume of the Village Creek Lift Gas shall be measured at Third Party Gatherer's meter number 22422.

[SIGNATURE PAGE FOLLOWS]

40

PORTIONS OF THIS EXHIBIT DENOTED WITH THREE ASTERISKS (***) HAVE BEEN OMITTED PURSUANT TO A REQUEST FOR CONFIDENTIAL TREATMENT

IN WITNESS WHEREOF, the Parties hereto have executed this Agreement in several originals as of the Effective Date.

PRODUCER

BlueStone Natural Resources II, LLC, a

Delaware limited liability company

By:    John Redmond            

Name:    John Redmond

Title:    President/Chief Executive Officer                    

GATHERER

Cowtown Pipeline Partners L.P., a Texas                             limited partnership

By:    Crestwood Gas Services Operating

GP LLC, its General partner

By:    J. Heath Deneke        

Name: J. Heath Deneke

Title: Chief Operating Officer and                                 President, Pipeline Services Group

41

PORTIONS OF THIS EXHIBIT DENOTED WITH THREE ASTERISKS (***) HAVE BEEN OMITTED PURSUANT TO A REQUEST FOR CONFIDENTIAL TREATMENT

EXHIBIT A

to the

GAS GATHERING AGREEMENT

This Exhibit A is attached to the Gas Gathering Agreement (the "Agreement") dated effective April 1, 2016 by and between BlueStone Natural Resources II, LLC, as Producer, and Cowtown Pipeline Partners L.P., as Gatherer, and made a part thereof for all purposes. All defined terms used herein shall have the same meaning as set forth in the Agreement.

Contract Area

Tarrant County, Texas.LeasesSee attached sheets.

Exhibit A Page 1

PORTIONS OF THIS EXHIBIT DENOTED WITH THREE ASTERISKS (***) HAVE BEEN OMITTED PURSUANT TO A REQUEST FOR CONFIDENTIAL TREATMENT

ST	County	File ID	Lessor	Lease Dated	Recorded County	Instrument No.
TX	TARRANT	TX4390002.01	MICHAEL C OLCOTT	3/25/2005	TARRANT	D205143296
TX	TARRANT	TX4390002.02	MARY SUSAN OLCOTT	6/20/2005	TARRANT	D205177448
TX	TARRANT	TX4390002.03	OLCOTT TRUSTS FROST BK TR	9/15/2005	TARRANT	D205281911
TX	TARRANT	TX4390003.01	LUCILLA S GARRETT	4/5/2005	TARRANT	D205138067
TX	TARRANT	TX4390003.02	JOHN B SARTAIN	4/5/2005	TARRANT	D205138066
TX	TARRANT	TX4390003.03	J EDWARD SARTAIN	4/5/2005	TARRANT	D205163408
TX	TARRANT	TX4390004.00	JACK R MCLAUGHLIN TRUSTEE	1/19/2005	TARRANT	D205170539
TX	TARRANT	TX4390005.00	S L SIBERT COMPANY INC	5/12/2005	TARRANT	D205163412
TX	TARRANT	TX4390006.00	303 BUSINESS PARK VENTURE	5/12/2005	TARRANT	D205170540
TX	TARRANT	TX4390011.00	ELMER E HUBBLE ET UX	4/7/2005	TARRANT	D205110052
TX	TARRANT	TX4390017.00	820/MARTIN DEVELOPMENT LP	4/14/2005	TARRANT	D205112088
TX	TARRANT	TX4390021.00	VIVIENNE B WILLIAMS ET AL	7/1/2005	TARRANT	D205255638
TX	TARRANT	TX4390026.00	E-DOR LTD	4/29/2005	TARRANT	D205163411
TX	TARRANT	TX4390027.01	JOHN MICHAEL DAVIS	12/5/2005	TARRANT	D206017041
TX	TARRANT	TX4390027.02	LINDA RADER OVERMAN	9/2/2005	TARRANT	D205342980
TX	TARRANT	TX4390027.03	WEB MADDOX TRUST	9/20/2005	TARRANT	D205281913
TX	TARRANT	TX4390027.04	ROSALIE ANN RADER	8/30/2005	TARRANT	D205281912
TX	TARRANT	TX4390027.05	BETTY J. MOORE	6/10/2005	TARRANT	D205220506
TX	TARRANT	TX4390027.06	JOHN N FRY	6/10/2005	TARRANT	D205209263
TX	TARRANT	TX4390027.07	CAROLYN CAMPBELL	6/10/2005	TARRANT	D205209264
TX	TARRANT	TX4390027.08	GRAYCE H. DAVIS	6/14/2005	TARRANT	D205209265
TX	TARRANT	TX4390027.09	ROSEMARY HULBURT	6/10/2005	TARRANT	D205209266
TX	TARRANT	TX4390027.10	ROBERT N RADER	6/24/2005	TARRANT	D205209267
TX	TARRANT	TX4390027.11	SHARON FOX	6/21/2005	TARRANT	D205220505
TX	TARRANT	TX4390027.12	JUDITH E BEEBE	6/27/2005	TARRANT	D205220504
TX	TARRANT	TX4390027.13	JAMES NEWTON	6/29/2005	TARRANT	D205220502
TX	TARRANT	TX4390027.14	PAT PACKARD	7/1/2005	TARRANT	D205220501
TX	TARRANT	TX4390027.15	GERALD S NEWTON	6/29/2005	TARRANT	D205220503
TX	TARRANT	TX4390027.16	EDWARD TUCKER MUSE	6/23/2006	TARRANT	D206220923
TX	TARRANT	TX4390027.17	EWELL H MUSE	6/23/2006	TARRANT	D206220922
	TARRANT	TX4390027.17	EWELL H MUSE	6/23/2006	TARRANT	D207112377
TX	TARRANT	TX4390027.18	BILLIE B MOSITES TRUSTEE	10/4/2006	TARRANT	D206323151
TX	TARRANT	TX4390027.19	CHERYL A MOSITES	10/4/2006	TARRANT	D206323152
TX	TARRANT	TX4390027.20	DUVONNE C MOSITES	10/4/2006	TARRANT	D206323153
TX	TARRANT	TX4390027.21	CRISTIE L MOSITES	10/4/2006	TARRANT	D206323154
TX	TARRANT	TX4390027.22	LORI D MOSITES	10/4/2006	TARRANT	D206323155

Exhibit A Page 2

PORTIONS OF THIS EXHIBIT DENOTED WITH THREE ASTERISKS (***) HAVE BEEN OMITTED PURSUANT TO A REQUEST FOR CONFIDENTIAL TREATMENT

TX	TARRANT	TX4390027.23	EWELL H MUSE III	2/5/2007	TARRANT	D207088320
TX	TARRANT	TX4390027.24	EDWARD TUCKER MUSE	2/5/2007	TARRANT	D207088319
TX	TARRANT	TX4390027.25	JESSICA CADWELL	5/30/2007	TARRANT	D207233344
TX	TARRANT	TX4390027.26	KRISTINE ASHTON	5/9/2007	TARRANT	D207217310
TX	TARRANT	TX4390027.27	DOUGLAS CADWELL	5/9/2007	TARRANT	D207217311
TX	TARRANT	TX4390027.28	E P MADDOX III	9/27/2007	TARRANT	D207408114
TX	TARRANT	TX4390027.29	F CHRIS FARKAS TRUST	12/19/2007	TARRANT	D208001564
TX	TARRANT	TX4390027.30	DAUN CRAIG FARKAS	11/5/2007	TARRANT	D208024437
TX	TARRANT	TX4390027.31	EDWARD M MUSE TRUST	11/30/2007	TARRANT	D207450509
TX	TARRANT	TX4390027.32	NANCY LEE BASS	11/30/2007	TARRANT	D207450510
TX	TARRANT	TX4390027.33	NANCY MUSE LEE BASS	4/16/2009	TARRANT	D209125162
TX	TARRANT	TX4390027.34	LUCY RYAN MUSE	4/16/2009	TARRANT	D209125163
TX	TARRANT	TX4390027.35	EDWARD M MUSE TRUST	4/16/2009	TARRANT	D209125164
TX	TARRANT	TX4390027.36	LINDA RADER OVERMAN	4/16/2009	TARRANT	D209134576
TX	TARRANT	TX4390027.37	CAROLYN CAMPBELL	4/16/2009	TARRANT	D209134577
TX	TARRANT	TX4390027.38	SHARON FOX	4/16/2009	TARRANT	D209134578
TX	TARRANT	TX4390027.39	PATRICIA L PACKARD	4/16/2009	TARRANT	D209134579
TX	TARRANT	TX4390027.40	GERALD S NEWTON	4/16/2009	TARRANT	D209134580
TX	TARRANT	TX4390027.41	JAMES A NEWTON	4/16/2009	TARRANT	D209134581
TX	TARRANT	TX4390027.42	JOHN N FRY	4/16/2009	TARRANT	D209134583
TX	TARRANT	TX4390027.43	GRAYCE H DAVIS	4/16/2009	TARRANT	D209134582
TX	TARRANT	TX4390027.44	JUDITH E BEEBE	4/16/2009	TARRANT	D209145772
TX	TARRANT	TX4390027.45	ROSALIE ANN RADER	4/16/2009	TARRANT	D209145770
TX	TARRANT	TX4390027.46	CADWELL-MCCLEEREY FM TR	4/16/2009	TARRANT	D209159509
TX	TARRANT	TX4390027.47	JESSICA CADWELL	4/16/2009	TARRANT	D209154618
TX	TARRANT	TX4390027.48	ROSEMARY HULBURT	4/16/2009	TARRANT	D209154620
TX	TARRANT	TX4390027.49	JOHN MICHAEL DAVIS	4/16/2009	TARRANT	D209154623
TX	TARRANT	TX4390027.50	ROBERT N RADER	4/16/2009	TARRANT	D209154622
TX	TARRANT	TX4390027.51	DONO W MOORE	6/15/2009	TARRANT	D209175671
TX	TARRANT	TX4390027.52	KRISTINE WITHAM	6/30/2009	TARRANT	D209197945
TX	TARRANT	TX4390027.53	F CHRIS FARKAS TESTAMENTARY TR	4/23/2010	TARRANT	D210111114
TX	TARRANT	TX4390029.00	SOUTH LOOP 820 LP	5/9/2005	TARRANT	D205185617
	TARRANT	TX4390029.00	SOUTH LOOP 820 LP	5/9/2005
TX	TARRANT	TX4390030.00	SCI TEXAS FUNERAL SERVICES	6/24/2005	TARRANT	D205195024
TX	TARRANT	TX4390031.00	ROBERT F HENDERSON ET UX	4/30/2005	TARRANT	D205195025
TX	TARRANT	TX4390034.00	SUN VALLEY INDUSTRIAL PARK	5/9/2005	TARRANT	D205209268

Exhibit A Page 3

PORTIONS OF THIS EXHIBIT DENOTED WITH THREE ASTERISKS (***) HAVE BEEN OMITTED PURSUANT TO A REQUEST FOR CONFIDENTIAL TREATMENT

TX	TARRANT	TX4390034.00	SUN VALLEY INDUSTRIAL PARK	5/9/2005	TARRANT	D208369012
TX	TARRANT	TX4390035.00	AL RAY BULLS JR	6/14/2005	TARRANT	D205209269
TX	TARRANT	TX4390036.00	DJK INC	11/30/2005	TARRANT	D206067890
TX	TARRANT	TX4390037.00	SHERRY LAWHON ET VIR	1/27/2006	TARRANT	D206067887
TX	TARRANT	TX4390038.00	G L HARRIS ET UX	2/8/2006	TARRANT	D206067888
TX	TARRANT	TX4390040.00	AEROSPACE OPTICS INC	2/7/2006	TARRANT	D206067889
TX	TARRANT	TX4390041.00	FRANK NGUYEN ET UX	8/12/2005	TARRANT	D206094635
TX	TARRANT	TX4390042.00	BOBBY DAVIS	2/21/2006	TARRANT	D206094636
TX	TARRANT	TX4390044.00	JOY LYNN THOMPSON	3/27/2006	TARRANT	D206123050
TX	TARRANT	TX4390046.00	THOMAS E CAESAR ET UX	2/8/2006	TARRANT	D206162967
TX	TARRANT	TX4390047.00	GARY E NICHOLS ET UX	5/18/2006	TARRANT	D206162970
TX	TARRANT	TX4390062.00	LAWHON INC	11/11/2005	TARRANT	D205384590
TX	TARRANT	TX4390063.00	LARRY PEABODY EXEC	11/23/2005	TARRANT	D205384591
TX	TARRANT	TX4390064.00	ROBERT WARD WILLIAMS	11/18/2005	TARRANT	D205384592
TX	TARRANT	TX4390065.00	SHERRY LAWHON ET VIR	11/11/2005	TARRANT	D205384593
TX	TARRANT	TX4390086.00	RONALD W WERTZ	7/27/2005	TARRANT	D205264967
TX	TARRANT	TX4390087.00	WHIZ-Q INC	8/3/2005	TARRANT	D205264965
TX	TARRANT	TX4390087.00	WHIZ-Q INC	8/3/2005
TX	TARRANT	TX4390088.00	OVERNITE TRANSPORATION CO	8/10/2005	TARRANT	D205281914
TX	TARRANT	TX4390089.00	PITTMAN CONSTRUCTION INC	8/7/2005	TARRANT	D205281917
TX	TARRANT	TX4390091.00	W H GROVE ESTATE	9/20/2005	TARRANT	D205281915
TX	TARRANT	TX4390096.00	BOWER & PARKER INV INC	8/12/2005	TARRANT	D205292845
TX	TARRANT	TX4390098.00	EASTLAND REAL ESTATE INV	10/24/2005	TARRANT	D205342984
TX	TARRANT	TX4390099.00	JUDEA MISSIONARY BAPTIST	9/1/2005	TARRANT	D205342983
TX	TARRANT	TX4390100.00	BWW TRUST	10/14/2005	TARRANT	D205342982
TX	TARRANT	TX4390101.00	BWW TRUST	9/30/2005	TARRANT	D205342981
TX	TARRANT	TX4390104.00	WORLD MISSIONARY BAPTIST	9/1/2005	TARRANT	D205297236
TX	TARRANT	TX4390105.00	UNLIMITED FAITH II LLC	9/1/2005	TARRANT	D205297235
TX	TARRANT	TX4390106.00	WILLIE D STRAWTHER ET UX	8/22/2005	TARRANT	D205297234
TX	TARRANT	TX4390108.00	GARY M REEDER	8/10/2005	TARRANT	D205292850
TX	TARRANT	TX4390109.00	LAWHON INC	8/1/2005	TARRANT	D205292849
TX	TARRANT	TX4390113.00	PHILIP H TREW JR	2/1/2006	TARRANT	D206034818
TX	TARRANT	TX4390114.00	WILLIE E MULKEY ET UX	5/4/2006	TARRANT	D206187077
TX	TARRANT	TX4390115.01	F WILLIAM BUEHLER III	5/25/2006	TARRANT	D206242430
TX	TARRANT	TX4390115.01	F WILLIAM BUEHLER III	5/25/2006	TARRANT	D206187078

Exhibit A Page 4

PORTIONS OF THIS EXHIBIT DENOTED WITH THREE ASTERISKS (***) HAVE BEEN OMITTED PURSUANT TO A REQUEST FOR CONFIDENTIAL TREATMENT

TX	TARRANT	TX4390115.02	PHYLLIS D THOMAS	5/25/2006	TARRANT	D206242431
TX	TARRANT	TX4390115.02	PHYLLIS D THOMAS	5/25/2006	TARRANT	D206187079
TX	TARRANT	TX4390116.00	G & P PROPERTIES	5/18/2006	TARRANT	D206187080
TX	TARRANT	TX4390117.00	JIM TALLY ET UX	5/8/2006	TARRANT	D206187081
TX	TARRANT	TX4390118.00	OLLIE STRAWN ET UX	5/16/2006	TARRANT	D206187083
TX	TARRANT	TX4390119.00	CHARLES E TAGG	5/16/2006	TARRANT	D206187084
TX	TARRANT	TX4390122.00	NELDA TOMLIN MCCASLIN	5/9/2006	TARRANT	D206203381
TX	TARRANT	TX4390126.00	AL RAY BULLS JR	6/14/2005	TARRANT	D205209270
TX	TARRANT	TX4390127.00	LAWHON INC	6/10/2005	TARRANT	D205209271
TX	TARRANT	TX4390128.00	LAWHON INC	6/10/2005	TARRANT	D205241494
TX	TARRANT	TX4390129.00	LOUIS LAND COMPANY LTD	5/27/2005	TARRANT	D205220500
TX	TARRANT	TX4390129.00	LOUIS LAND COMPANY LTD	5/27/2005	TARRANT
TX	TARRANT	TX4390130.00	WESTWIND ENTERPRISES LTD	7/21/2005	TARRANT	D205231012
TX	TARRANT	TX4390133.00	OAK CREEK HOUSING PROP LP	11/23/2005	TARRANT	D206033401
TX	TARRANT	TX4390135.00	ERNEST THOMAS ET UX	12/20/2005	TARRANT	D206052095
TX	TARRANT	TX4390136.00	LAWHON INC	1/3/2006	TARRANT	D206033402
TX	TARRANT	TX4390137.00	ERNEST THOMAS ET UX	12/20/2005	TARRANT	D206052094
TX	TARRANT	TX4390138.00	ERNEST THOMAS ET UX	12/20/2005	TARRANT	D206052093
TX	TARRANT	TX4390140.00	JO ANN THOMAS ET VIR	12/20/2005	TARRANT	D206052091
TX	TARRANT	TX4390141.00	ERNEST THOMAS ET UX	12/20/2005	TARRANT	D206052090
TX	TARRANT	TX4390143.00	ALBERT CARRILLO	6/8/2006	TARRANT	D206220930
TX	TARRANT	TX4390144.01	JOYCE ANN PUTMAN	6/10/2006	TARRANT	D206220928
TX	TARRANT	TX4390144.02	LUTHER D PUTMAN	6/10/2006	TARRANT	D206220929
TX	TARRANT	TX4390145.00	JWV ASSOC LTD	6/14/2006	TARRANT	D206220927
TX	TARRANT	TX4390145.00	JWV ASSOC LTD	6/14/2006	TARRANT	D206254039
TX	TARRANT	TX4390147.00	ROOTIN-TOOTIN PROP LP	6/14/2006	TARRANT	D206235885
TX	TARRANT	TX4390148.00	HARRY MCDANIEL ET UX	6/21/2006	TARRANT	D206235886
TX	TARRANT	TX4390149.00	YEN NGUYEN	7/12/2006	TARRANT	D206235887
TX	TARRANT	TX4390150.01	ARNOLD D HOLLEMAN ET AL	6/28/2006	TARRANT	D206235888
TX	TARRANT	TX4390150.02	MILTON L CHAPMAN ET UX	2/1/2010	TARRANT	D210054069
TX	TARRANT	TX4390150.03	GEORGE WILLIAM CHAPMAN JR	4/1/2010	TARRANT	D210083646
TX	TARRANT	TX4390150.04	LONNIE CHANCE	4/1/2010	TARRANT	D210093228
TX	TARRANT	TX4390150.05	DELORES IDA WEIL	4/1/2010	TARRANT	D210093227
TX	TARRANT	TX4390150.06	VICKIE L WARNKE	4/1/2010	TARRANT	D210093229

Exhibit A Page 5

PORTIONS OF THIS EXHIBIT DENOTED WITH THREE ASTERISKS (***) HAVE BEEN OMITTED PURSUANT TO A REQUEST FOR CONFIDENTIAL TREATMENT

TX	TARRANT	TX4390150.07	GINGER L BODIFORD	4/1/2010	TARRANT	D210093226
TX	TARRANT	TX4390150.08	SHIRLEY BLEVINS	4/1/2010	TARRANT	D210095770
TX	TARRANT	TX4390150.09	KATHLEEN ANN WHALAN	4/15/2010	TARRANT	D210114851
TX	TARRANT	TX4390150.10	JUSTIN HOLLEMAN	5/15/2010	TARRANT	D210115328
TX	TARRANT	TX4390150.11	LINDA JEAN OLLIS	4/28/2010	TARRANT	D210126174
TX	TARRANT	TX4390150.12	CLAYTON PARSONS	5/19/2010	TARRANT	D210117991
TX	TARRANT	TX4390150.13	GARY CHANCE ET UX	5/18/2010	TARRANT	D210131549
TX	TARRANT	TX4390150.14	DONALD MILAM ET UX	5/18/2010	TARRANT	D210131550
TX	TARRANT	TX4390150.15	AMANDA LEIGH HOLLEMAN	4/27/2010	TARRANT	D210131551
TX	TARRANT	TX4390150.16	ALMA FAYE LEWIS	6/2/2010	TARRANT	D210131548
TX	TARRANT	TX4390151.00	LORETTA ORTEGA ET VIR	6/22/2006	TARRANT	D206220925
TX	TARRANT	TX4390152.00	ANCIENT OAKS LTD	7/26/2006	TARRANT	D206229201
TX	TARRANT	TX4390153.00	POOR BOYS PROPERTIES	6/14/2006	TARRANT	D206235884
TX	TARRANT	TX4390154.00	NGOCANH THI TRAN & N D BUI	6/15/2006	TARRANT	D206220924
TX	TARRANT	TX4390155.00	RICKEY LEE STRAWN SR ET UX	5/16/2006	TARRANT	D206187082
TX	TARRANT	TX4390156.00	CITY OF ARLINGTON	10/18/2006	TARRANT	D206329299
TX	TARRANT	TX4390156.00	CITY OF ARLINGTON	10/18/2006
TX	TARRANT	TX4390156.00	CITY OF ARLINGTON	10/18/2006
TX	TARRANT	TX4390156.00	CITY OF ARLINGTON	10/18/2006
TX	TARRANT	TX4390156.00	CITY OF ARLINGTON	10/18/2006
TX	TARRANT	TX4390156.00	CITY OF ARLINGTON	10/18/2006
TX	TARRANT	TX4390157.00	VALUE FAM PROP SUMMERLAKE	6/26/2006	TARRANT	D206278075
TX	TARRANT	TX4390158.00	TRIUMPH FABRICATIONS FW	7/26/2006	TARRANT	D206279354
TX	TARRANT	TX4390159.00	WILLIAM A STANLEY ET UX	7/19/2006	TARRANT	D206254040
TX	TARRANT	TX4390160.00	DAN DIPERTS TRAVEL SERV	7/20/2006	TARRANT	D206254041
TX	TARRANT	TX4390161.00	G M & B A COOPER FAMILY TR	7/18/2006	TARRANT	D206254042
TX	TARRANT	TX4390165.00	ARC COM 3 EL LAGO	8/1/2006	TARRANT	D206242434
TX	TARRANT	TX4390168.00	JERRY C MOYES ET UX	9/19/2006	TARRANT	D206325108
TX	TARRANT	TX4390168.00	JERRY C MOYES ET UX	9/19/2006	TARRANT	D208423737
TX	TARRANT	TX4390169.00	TXU MINERAL DEV CO LP	10/13/2006	TARRANT	D206325109
TX	TARRANT	TX4390169.00	TXU MINERAL DEV CO LP	10/13/2006
TX	TARRANT	TX4390169.00	TXU MINERAL DEV CO LP	10/13/2006

Exhibit A Page 6

PORTIONS OF THIS EXHIBIT DENOTED WITH THREE ASTERISKS (***) HAVE BEEN OMITTED PURSUANT TO A REQUEST FOR CONFIDENTIAL TREATMENT

TX	TARRANT	TX4390169.00	TXU MINERAL DEV CO LP	10/13/2006
TX	TARRANT	TX4390170.00	RICHARD WARREN	9/21/2006	TARRANT	D206325107
TX	TARRANT	TX4390171.00	FEDEX GROUND PACKAGE SYS	5/19/2006	TARRANT	D206325106
TX	TARRANT	TX4390172.00	SHERRY LAWHON ET VIR	9/22/2006	TARRANT	D206325105
TX	TARRANT	TX4390173.00	ROBERT DANIEL RUSSELL	10/11/2006	TARRANT	D206323157
TX	TARRANT	TX4390175.00	EBENEZER MISSIONARY BAPTIS	8/9/2006	TARRANT	D206325104
TX	TARRANT	TX4390181.00	JAMES DORSEY ET UX	8/1/2006	TARRANT	D206319456
TX	TARRANT	TX4390182.00	303 JOINT VENTURE	11/15/2006	TARRANT	D206362872
TX	TARRANT	TX4390184.99	303 BUSINESS PARK VENTURE	2/15/2007	TARRANT	D207058579
TX	TARRANT	TX4390185.00	JAMES RICHARD NACHLINGER	10/4/2006	TARRANT	D206329673
TX	TARRANT	TX4390186.00	ALLAGENE CAUDLE	9/18/2006	TARRANT	D206329674
TX	TARRANT	TX4390209.00	EASTLAND REAL ESTATE INV	9/22/2006	TARRANT	D206390216
TX	TARRANT	TX4390210.00	J BIMER & DERMARDIROSSIAN	7/22/2006	TARRANT	D206329675
TX	TARRANT	TX4390212.00	RICHARD R BRADSHAW ET UX	10/18/2006	TARRANT	D206390218
TX	TARRANT	TX4390213.00	GOOD SHEPARD TEMPLE OF PRA	9/19/2006	TARRANT	D206390219
TX	TARRANT	TX4390215.00	RUBY L STOY	10/10/2006	TARRANT	D206390220
TX	TARRANT	TX4390216.00	RICHARD DORSETT ET UX	10/26/2006	TARRANT	D206402250
TX	TARRANT	TX4390217.00	CALEAST NAT TEXAS LP	8/1/2006	TARRANT	D206402249
TX	TARRANT	TX4390220.01	PATRICIA A PENNINGTON	11/17/2006	TARRANT	D207038208
TX	TARRANT	TX4390220.02	GARY W GARDNER	11/17/2006	TARRANT	D207029761
TX	TARRANT	TX4390220.03	JACK V GARDNER	11/17/2006	TARRANT	D207029762
TX	TARRANT	TX4390220.04	LARRY J GARDNER	11/17/2006	TARRANT	D207029763
TX	TARRANT	TX4390220.05	RONALD S GARDNER	11/17/2006	TARRANT	D207029764
TX	TARRANT	TX4390220.06	GENTRY FAMILY LIVING TRUST	11/17/2006	TARRANT	D207029765
TX	TARRANT	TX4390220.07	DENISE PENNINGTON	11/17/2006	TARRANT	D207029766
TX	TARRANT	TX4390220.08	PAULA L PENNINGTON	11/17/2006	TARRANT	D207029767
TX	TARRANT	TX4390221.00	WAYNE ALLEN SMITH	1/12/2007	TARRANT	D207038209 not in file
TX	TARRANT	TX4390222.00	DENNIS M WILLIAMS ET UX	1/12/2007	TARRANT	D207038210

Exhibit A Page 7

PORTIONS OF THIS EXHIBIT DENOTED WITH THREE ASTERISKS (***) HAVE BEEN OMITTED PURSUANT TO A REQUEST FOR CONFIDENTIAL TREATMENT

TX	TARRANT	TX4390223.00	GLENDA COLBURN	12/28/2006	TARRANT	D207029768
TX	TARRANT	TX4390258.00	ELDON F ESSEX ET UX	4/20/2007	TARRANT	D207160562
TX	TARRANT	TX4390259.00	TERRI DAWN DELPHO	4/20/2007	TARRANT	D207160561
TX	TARRANT	TX4390262.00	ERNEST W THOMAS ET UX	3/20/2007	TARRANT	D207141710
TX	TARRANT	TX4390265.00	ROBERT DANIEL RUSSELL	4/20/2007	TARRANT	D207160558
TX	TARRANT	TX4390266.00	JAMES RICHARD NACHLINGER	4/20/2007	TARRANT	D207160560
TX	TARRANT	TX4390267.00	EXELON PEAKER DEV LLP	6/8/2007	TARRANT	D207204341
TX	TARRANT	TX4390271.00	TIMOTHY DUANE ARMSTRONG	5/5/2007	TARRANT	D207171407
TX	TARRANT	TX4390284.00	RUDOLPH VASQUEZ ET UX	4/24/2007	TARRANT	D207176507
TX	TARRANT	TX4390303.00	MARY STEWART	7/3/2007	TARRANT	D207264090
TX	TARRANT	TX4390319.00	VASS'E ENTERPRISES INC	7/11/2007	TARRANT	D207263720
TX	TARRANT	TX4390328.00	CASCO PROPERTIES	7/12/2007	TARRANT	D207288508
TX	TARRANT	TX4390334.00	ST TX 108059	7/17/2007	TARRANT	D207310986
TX	TARRANT	TX4390343.00	LOLA C VECERA	9/1/2007	TARRANT	D207336954
TX	TARRANT	TX4390347.00	TARRANT COUNTY	10/7/2007	TARRANT	D207372463
TX	TARRANT	TX4390348.00	CITY OF FORT WORTH	1/1/2008	TARRANT	D208008423
TX	TARRANT	TX4390352.00	JAMES W GADDY ET UX	10/19/2007	TARRANT	D207384417
TX	TARRANT	TX4390353.00	LARRY RIGGAN	11/2/2007	TARRANT	D207409033
TX	TARRANT	TX4390355.00	NORVILLE LEWIS RIGGAN SR	11/12/2007	TARRANT	D207432550
TX	TARRANT	TX4390373.00	ERNEST W THOMAS ET UX	11/14/2007	TARRANT	D207459982
TX	TARRANT	TX4390374.00	SUNAKO RICHEY ET VIR	11/14/2007	TARRANT	D207458160
TX	TARRANT	TX4390375.00	GARY LYNN COLBURN	11/29/2007	TARRANT	D207459983
TX	TARRANT	TX4390376.00	EDWARD J MALONE ET UX	11/30/2007	TARRANT	D207459984
TX	TARRANT	TX4390379.00	G W WILLIAMS	12/12/2007	TARRANT	D207459985
TX	TARRANT	TX4390380.00	ROBERT W MCCREARY ET UX	9/21/2007	TARRANT	D207459986
TX	TARRANT	TX4390381.00	JOHN J KOSLOW ET UX	11/30/2007	TARRANT	D207458155
TX	TARRANT	TX4390382.00	TONY LEROY BLACK	11/30/2007	TARRANT	D207458157
TX	TARRANT	TX4390383.00	DORIS MARIE HUNT	12/10/2007	TARRANT	D207458156
TX	TARRANT	TX4390384.00	LUMINANT MINERAL DEV CO	12/21/2007	TARRANT	D208037639
TX	TARRANT	TX4390386.00	LUTHER M PARKERSON ET UX	1/31/2008	TARRANT	D208093950

Exhibit A Page 8

PORTIONS OF THIS EXHIBIT DENOTED WITH THREE ASTERISKS (***) HAVE BEEN OMITTED PURSUANT TO A REQUEST FOR CONFIDENTIAL TREATMENT

TX	TARRANT	TX4390387.00	PTC PARTNERS LTD	1/31/2008	TARRANT	D208093949
TX	TARRANT	TX4390388.00	JO ELLEN MATHEWS	2/21/2008	TARRANT	D208113675
TX	TARRANT	TX4390389.00	SAM L SHUGART AKA SAMMY	2/18/2008	TARRANT	D208113672
TX	TARRANT	TX4390390.00	KENNETH MORTON ET UX	2/5/2008	TARRANT	D208113671
TX	TARRANT	TX4390391.00	JOSE C CARDONA	2/11/2008	TARRANT	D208113673
TX	TARRANT	TX4390392.00	LANNETTE WOODROW	2/26/2008	TARRANT	D208113670
TX	TARRANT	TX4390394.00	CORRAL FENCE CO	3/21/2008	TARRANT	D208174274
TX	TARRANT	TX4390405.00	KEITH A KIDWILL	4/18/2008	TARRANT	D208152721
TX	TARRANT	TX4390405.00	KEITH A KIDWILL	4/18/2008	TARRANT	D208406666
TX	TARRANT	TX4390406.00	ROY D JACQUOT JR	3/19/2008	TARRANT	D208160570
TX	TARRANT	TX4390409.00	ALPHA INDUSTRIES INC	3/14/2008	TARRANT	D208174784
TX	TARRANT	TX4390412.00	OAKWOOD BAPTIST CHURCH	2/15/2008	TARRANT	208113674
TX	TARRANT	TX4390416.00	NATHANIEL HALL ET UX	4/11/2008	TARRANT	208196888
TX	TARRANT	TX4390421.01	LLOYD C BLAIR	6/4/2008	TARRANT	D208256955
TX	TARRANT	TX4390422.01	REBEL REALTY INC	6/4/2008	TARRANT	D208256953
TX	TARRANT	TX4390423.99	REBEL REALTY INC	6/30/2008	TARRANT	D208255102
TX	TARRANT	TX4390423.99	REBEL REALTY INC	6/30/2008	TARRANT	D211097209
TX	TARRANT	TX4390424.99	LLOYD C BLAIR	6/30/2008	TARRANT	D208255101
TX	TARRANT	TX4390428.00	IMPERIAL EAGLE INVESTMENTS	6/30/2008	TARRANT	D208293788
TX	TARRANT	TX4390429.00	JUAN HERNANDEZ	6/4/2008	TARRANT	D210004987
TX	TARRANT	TX4390430.00	ENRIQUE L CASAS ET UX	6/4/2008	TARRANT	D208293787
TX	TARRANT	TX4390431.00	BETTY J DRAGOO	7/29/2008	TARRANT	D208378505
TX	TARRANT	TX4390433.00	LEWIS WALKER ET UX	6/13/2008	TARRANT	D208326302
TX	TARRANT	TX4390434.00	LUBERTA FULLILOVE	6/13/2008	TARRANT	D208326301
TX	TARRANT	TX4390435.00	SAMANTHA MCCOOL	6/4/2008	TARRANT	D208326300
TX	TARRANT	TX4390505.00	JIMMY R KERSEY ET UX	6/30/2008	TARRANT	D208326305
TX	TARRANT	TX4390513.00	JAMES L BRADDEN JR	7/7/2008	TARRANT	D208378509
TX	TARRANT	TX4390514.00	MARY FOSTER	6/26/2008	TARRANT	D208326306
TX	TARRANT	TX4390516.00	SHERRY J LAWHON ET VIR	7/19/2008	TARRANT	D208347986
TX	TARRANT	TX4390516.00	SHERRY J LAWHON ET VIR	7/19/2008
TX	TARRANT	TX4390517.00	SHERRY J LAWHON ET VIR	7/19/2008	TARRANT	D208378506
TX	TARRANT	TX4390517.00	SHERRY J LAWHON ET VIR	7/19/2008
TX	TARRANT	TX4390518.00	RICHARD L WATKINS ET UX	6/4/2008	TARRANT	D208378508
TX	TARRANT	TX4390522.01	BRUCE D BRADHAM ET UX	8/29/2008	TARRANT	D208346476
TX	TARRANT	TX4390522.02	KENNETH MICHAEL HILL ET UX	8/29/2008	TARRANT	D208346477
TX	TARRANT	TX4390525.00	DAVID YORK	8/11/2008	TARRANT	D208416398
TX	TARRANT	TX4390529.00	VERNA L TAYLOR	7/22/2008	TARRANT	D208416397
TX	TARRANT	TX4390530.00	LEOPOLDO FRANCO ET UX	8/13/2008	TARRANT	D208416396

Exhibit A Page 9

PORTIONS OF THIS EXHIBIT DENOTED WITH THREE ASTERISKS (***) HAVE BEEN OMITTED PURSUANT TO A REQUEST FOR CONFIDENTIAL TREATMENT

TX	TARRANT	TX4390532.00	JESSE B AGUIRRE ET UX	8/9/2008	TARRANT	D208416401
TX	TARRANT	TX4390533.01	JOHN D ALEXANDER	7/15/2008	TARRANT	D208416392
TX	TARRANT	TX4390533.02	LOU NELL JOYNER	7/15/2008	TARRANT	D208416391
TX	TARRANT	TX4390533.03	J EARL ALEXANDER JR	7/15/2008	TARRANT	D208416390
TX	TARRANT	TX4390533.04	EDWARD H ALEXANDER	7/15/2008	TARRANT	D208416399
TX	TARRANT	TX4390533.05	CHRISTY DAWN WHEELER	12/2/2008	TARRANT	D209025877
TX	TARRANT	TX4390533.06	DANNY STREBECK	12/2/2008	TARRANT	D209025874
TX	TARRANT	TX4390533.07	RON STREBECK	12/8/2008	TARRANT	D209025876
TX	TARRANT	TX4390533.08	RITA HOPKINS ET VIR	12/2/2008	TARRANT	D209025875
TX	TARRANT	TX4390537.00	INDEPENDENT UTILITY CONSTR	8/26/2008	TARRANT	D208341454
TX	TARRANT	TX4390538.00	WILLIAMS PROPERTY COMPANY	8/26/2008	TARRANT	D208341453
TX	TARRANT	TX4390539.00	DAVID S HUMPHREY	8/15/2008	TARRANT	D208336089
TX	TARRANT	TX4390540.00	CW ROSS CONSTRUCTION INC	8/22/2008	TARRANT	D208336090
TX	TARRANT	TX4390542.00	ANDRES SOTO ET UX	8/26/2008	TARRANT	D208416402
TX	TARRANT	TX4390543.00	NELL MOORES	8/26/2008	TARRANT	D208416403
TX	TARRANT	TX4390544.00	LINDA THRELKELD	8/13/2008	TARRANT	D208416400
TX	TARRANT	TX4390545.00	SHRINERS HOSPITALS	6/27/2008	TARRANT	D208310231
TX	TARRANT	TX4390549.00	DC VANDERVOORT ET UX	9/27/2008	TARRANT	D208416415
TX	TARRANT	TX4390550.00	DANNY B BLACKWELL ET UX	8/26/2008	TARRANT	D208416409
TX	TARRANT	TX4390551.00	SOUTH CENTRAL INDUSTRIAL P	8/12/2008	TARRANT	D208416406
TX	TARRANT	TX4390552.00	DARRELL THOMPSON ET AL	8/26/2008	TARRANT	D208416407
TX	TARRANT	TX4390553.00	GEORGIA MAE BENNETT	8/11/2008	TARRANT	D208416408
TX	TARRANT	TX4390554.00	OLIN W GIBBINS	10/15/2008	TARRANT	D208447926
TX	TARRANT	TX4390556.00	CITY OF FORT WORTH	1/6/2009	TARRANT	D209011528
TX	TARRANT	TX4390557.00	PATRICIA ANN SINGLETON	8/31/2008	TARRANT	D208416414
TX	TARRANT	TX4390558.00	MIKE GUENTHER ET UX	8/31/2008	TARRANT	D208416412
TX	TARRANT	TX4390559.99	JULIA REESE	10/31/2008	TARRANT	D208432180
TX	TARRANT	TX4390563.99	JOE FERNANDEZ JR	10/24/2008	TARRANT	D208432179
TX	TARRANT	TX4390589.00	ELI VILLANUEVA	9/10/2008	TARRANT	D208416417
TX	TARRANT	TX4390591.00	METRO BUILDERS BY ANTANGA	9/12/2008	TARRANT	D208416386
TX	TARRANT	TX4390592.00	JAMES H AKINS	9/16/2008	TARRANT	D208416416
TX	TARRANT	TX4390593.00	JOSE ERIK MUNOZ	9/11/2008	TARRANT	D208416410
TX	TARRANT	TX4390596.00	MARK BARNES ET UX	9/2/2008	TARRANT	D208416411
TX	TARRANT	TX4390598.00	CAROLYN SPENCER	8/27/2008	TARRANT	D208411704
TX	TARRANT	TX4390677.00	JIMMY EARL REED ET UX	9/4/2008	TARRANT	D208464757
TX	TARRANT	TX4390728.00	GRACIE CAUGHRON BARNES	9/1/2008	TARRANT	D208411703

Exhibit A Page 10

PORTIONS OF THIS EXHIBIT DENOTED WITH THREE ASTERISKS (***) HAVE BEEN OMITTED PURSUANT TO A REQUEST FOR CONFIDENTIAL TREATMENT

TX	TARRANT	TX4390729.00	J REYES MORENO ET UX	9/30/2008	TARRANT	D208464758
TX	TARRANT	TX4390730.00	GARY D WINBERRY	10/14/2008	TARRANT	D208464756
TX	TARRANT	TX4390733.00	VIRGINIA KIMBRO ET AL	7/22/2004	TARRANT	D204250875
TX	TARRANT	TX4390759.00	MARTIN S MOORE ET UX	10/24/2008	TARRANT	D208422773
TX	TARRANT	TX4390761.00	PAUL GREGORY JOEL	9/14/2008	TARRANT	D208422772
TX	TARRANT	TX4390762.01	KATHERINE MAGAR	9/16/2008	TARRANT	D208411702
TX	TARRANT	TX4390762.02	JOHN F GOSS ET UX	9/16/2008	TARRANT	D208411701
TX	TARRANT	TX4390785.00	WILLIAM A RAGSDILL ET UX	9/15/2008	TARRANT	D208464762
TX	TARRANT	TX4390792.00	GOLDIE GINIGEME	10/1/2008	TARRANT	D209029813
TX	TARRANT	TX4390796.00	LAWRENCE CARLIS ET UX	10/6/2008	TARRANT	D208464765
TX	TARRANT	TX4390797.00	NELDA TOMLIN MCCASLIN	10/27/2008	TARRANT	D209029822
TX	TARRANT	TX4390798.00	COLE GUTIERREZ AKA LAWRENC	10/12/2008	TARRANT	D208464764
TX	TARRANT	TX4390799.00	PISCATUR PROPERTIES LLC	10/3/2008	TARRANT	D208464768
TX	TARRANT	TX4390802.00	MARY LOUISE FENN	11/16/2008	TARRANT	D209029818
TX	TARRANT	TX4390803.00	PAUL L THOMPSON	11/22/2008	TARRANT	D209029817
TX	TARRANT	TX4390805.00	MIKE HONEYCUTT	11/15/2008	TARRANT	D209029819
TX	TARRANT	TX4390806.00	HERMAS VENTURA JR	11/3/2008	TARRANT	D209029816
TX	TARRANT	TX4390808.00	ST TX 109585	12/16/2008	TARRANT	D209004253
TX	TARRANT	TX4390809.00	ST TX 109584	12/16/2008	TARRANT	D209004252
TX	TARRANT	TX4390812.00	FULL GOSPEL TABERNACLE	10/28/2008	TARRANT	D209029810
TX	TARRANT	TX4390813.00	AUGUSTIN TELLEZ ET UX	12/2/2008	TARRANT	D209029821
TX	TARRANT	TX4390815.00	NGOC D BUI ET UX	10/22/2008	TARRANT	D209029808
TX	TARRANT	TX4390819.00	MELINDA T FULLER	9/26/2008	TARRANT	D209029812
TX	TARRANT	TX4390820.01	JUDY ANN TATUM ET VIR	12/2/2008	TARRANT	D209029814
TX	TARRANT	TX4390820.02	SARAH LEANA LOONEY LEACH	1/11/2011	TARRANT	D211078070
TX	TARRANT	TX4390820.03	JONATHAN JACOB LEACH	1/29/2011	TARRANT	D211078071
TX	TARRANT	TX4390820.04	ELMER EUGENE LEACH	1/11/2011	TARRANT	D211122583
TX	TARRANT	TX4390823.00	JAMES W GADDY ET UX	11/24/2008	TARRANT	D209045298
TX	TARRANT	TX4390830.00	MICHAEL A FOSTER	12/5/2008	TARRANT	D209028324
TX	TARRANT	TX4390840.00	SILVERSAGE LTD	12/23/2008	TARRANT	D209038064

Exhibit A Page 11

PORTIONS OF THIS EXHIBIT DENOTED WITH THREE ASTERISKS (***) HAVE BEEN OMITTED PURSUANT TO A REQUEST FOR CONFIDENTIAL TREATMENT

TX	TARRANT	TX4390842.00	THE OAKRIDGE SCHOOL INC	11/16/2005	TARRANT	D206068688
TX	TARRANT	TX4390843.00	ROSE PITTMAN	10/8/2008	TARRANT	D209045304
TX	TARRANT	TX4390853.00	CITY OF FORT WORTH	2/26/2009	TARRANT	D209071940
TX	TARRANT	TX4390854.00	TRUCK TRAILER SERVICES INC	2/26/2009	TARRANT	D209082158
TX	TARRANT	TX4390860.00	PLANTATION PROPERTIES LTD	3/4/2009	TARRANT	D209082157
TX	TARRANT	TX4390861.00	LEWIS BULL CORPORATION	2/19/2009	TARRANT	D209082156
TX	TARRANT	TX4390862.00	ARNOLD ANCHONDO SR ET AL	3/2/2009	TARRANT	D209119324
TX	TARRANT	TX4390864.00	JORGE HERNANDEZ ET UX	2/28/2009	TARRANT	D209093865
TX	TARRANT	TX4390865.00	MERRILL A NELSON ET UX	3/25/2009	TARRANT	D209093866
TX	TARRANT	TX4390866.00	KYLE EQUITIES LP	3/25/2009	TARRANT	D209168074
TX	TARRANT	TX4390869.00	MOSSON LP	5/29/2009	TARRANT	D209168075
TX	TARRANT	TX4390879.00	CINDY D KAPPEL	2/12/2009	TARRANT	D209109105
TX	TARRANT	TX4390880.00	JIMMY R KERSEY ET UX	2/4/2009	TARRANT	D209109107
TX	TARRANT	TX4390882.00	TAMMIE Y DOUGLAS	3/26/2009	TARRANT	D209109106
TX	TARRANT	TX4390884.01	MARTHA ABERNATHY ET VIR	3/28/2009	TARRANT	D209109108
TX	TARRANT	TX4390884.02	BRENDA KILLINGSWORTH	3/28/2009	TARRANT	D209109109
TX	TARRANT	TX4390884.03	WILLIAM STEPHENS	2/1/2010	TARRANT	D210039890
TX	TARRANT	TX4390884.04	JAMES STEPHENS ET UX	2/19/2010	TARRANT	D210039891
TX	TARRANT	TX4390884.05	ANDREW GAGE	2/19/2010	TARRANT	D210039892
TX	TARRANT	TX4390884.06	MARY FRANCES SAENZ ET VIR	2/1/2010	TARRANT	D210039894
TX	TARRANT	TX4390884.07	MARGIE ERWIN ET VIR	2/1/2010	TARRANT	D210039893
TX	TARRANT	TX4390886.00	DANNY EADES ET UX	4/9/2009	TARRANT	D209109110
TX	TARRANT	TX4390888.00	JEWELL LANDERS JR ET UX	5/11/2009	TARRANT	D209134575
TX	TARRANT	TX4390889.00	ST TX 110047	4/7/2009	TARRANT	D209111987
TX	TARRANT	TX4390891.01	CHARLENE HIGH ET VIR	3/28/2009	TARRANT	D209125156
TX	TARRANT	TX4390891.02	ANTHONY MARTINEZ	3/28/2009	TARRANT	D209125155
TX	TARRANT	TX4390891.03	CONNIE SIMMONS ET VIR	3/25/2009	TARRANT	D209125157
TX	TARRANT	TX4390891.04	STEVEN W PITTMAN ET UX	3/28/2009	TARRANT	D209125158
TX	TARRANT	TX4390891.05	ROSE PITTMAN	4/20/2009	TARRANT	D209119323
TX	TARRANT	TX4390891.06	TANNA MARTINEZ	2/15/2010	TARRANT	D210046611
TX	TARRANT	TX4390895.00	EASTLAND REAL ESTATE INV	3/23/2009	TARRANT	D209127371
TX	TARRANT	TX4390898.00	ROSALIA CERVANTES	4/10/2009	TARRANT	D209136881
TX	TARRANT	TX4390903.00	RAYMOND LESLIE WHALEY SR	5/14/2009	TARRANT	D209140939
TX	TARRANT	TX4390905.00	JAIME MORQUECHO	2/19/2009	TARRANT	D209145771
TX	TARRANT	TX4390912.00	MUGEER OMAR ET UX	5/6/2009	TARRANT	D209154621
TX	TARRANT	TX4390913.00	CITY OF FORT WORTH	6/16/2009	TARRANT	D209166519
TX	TARRANT	TX4390919.00	CITY OF FORT WORTH	6/25/2009	TARRANT	D209188093
TX	TARRANT	TX4390922.00	RUSTEM GASHI ET UX	6/18/2009	TARRANT	D209195609

Exhibit A Page 12

PORTIONS OF THIS EXHIBIT DENOTED WITH THREE ASTERISKS (***) HAVE BEEN OMITTED PURSUANT TO A REQUEST FOR CONFIDENTIAL TREATMENT

TX	TARRANT	TX4390925.00	ALEXANDER ALFARO ET UX	7/9/2009	TARRANT	D209209831
TX	TARRANT	TX4390936.00	SCOTT HENSEL	7/21/2009	TARRANT	D209220526
TX	TARRANT	TX4390940.00	ARCTX MINERALS LLC	9/4/2009	TARRANT	D209242224
TX	TARRANT	TX4390941.00	LARRY H JACKSON ET UX	8/17/2009	TARRANT	D209237004
TX	TARRANT	TX4390944.00	ELLIOTT AND LILLIAN LTD	9/18/2009	TARRANT	D209249790
TX	TARRANT	TX4390945.00	EMILIO H CANTU	3/26/2009	TARRANT	D209329178
TX	TARRANT	TX4390947.00	BLANCA GAONA	8/24/2009	TARRANT	D209248926
TX	TARRANT	TX4390948.00	DONALD K SIEWERT ET UX	8/4/2009	TARRANT	D209254721
TX	TARRANT	TX4390950.00	MINNIE LOUISE WESTBROOK	8/13/2009	TARRANT	D209269912
TX	TARRANT	TX4390951.00	MORROW FAMILY TRUST	10/19/2009	TARRANT	D209286755
TX	TARRANT	TX4390952.00	ARCTX MINERALS LLC	10/29/2009	TARRANT	D209295177
TX	TARRANT	TX4390953.00	ST TX MF-110325	10/6/2009	TARRANT	D209283998
TX	TARRANT	TX4390967.00	ROSARIO ALVARADO ET VIR	11/17/2009	TARRANT	D209327309
TX	TARRANT	TX4390969.99	ANNIE MAE RUDD	1/9/2010	TARRANT	D210006291
TX	TARRANT	TX4390970.00	JS PROPERTIES LP	12/1/2009	TARRANT	D210002550
TX	TARRANT	TX4390972.00	WALTER LEE TORRANCE	12/18/2009	TARRANT	D210002924
TX	TARRANT	TX4390973.00	REZA ALAVI	4/9/2009	TARRANT	D210004988
TX	TARRANT	TX4390974.00	REZA ALAVI	1/8/2010	TARRANT	D210008019
TX	TARRANT	TX4390975.00	CITY OF FORT WORTH	1/14/2010	TARRANT	D210013153
TX	TARRANT	TX4390976.99	ALAN SPARKS / MARY SPARKS AIF	2/3/2010	TARRANT	D210030172
TX	TARRANT	TX4390980.99	DENNIS DEAN JONES ET UX	1/25/2010	TARRANT	D210035126
TX	TARRANT	TX4390981.99	DONALD RAY JONES ET UX	1/25/2010	TARRANT	D210035127
TX	TARRANT	TX4390985.00	ST TX MF-110554	2/2/2010	TARRANT	D210039889
TX	TARRANT	TX4390991.99	MICHELLE D MORRISON ET AL	2/28/2010	TARRANT	D210086544
TX	TARRANT	TX4390992.00	GEARY S STOWE JR	2/8/2010	TARRANT	D210051486
TX	TARRANT	TX4390993.99	IDA DAMRON ET AL	6/30/2010	TARRANT	D210200632
TX	TARRANT	TX4390994.00	CITY OF FORT WORTH	3/15/2010	TARRANT	D210067244
TX	TARRANT	TX4390995.99	SAMUEL W OGDEN ET UX	3/31/2010	TARRANT	D210079049
TX	TARRANT	TX4390996.99	VICTOR P HARRISON ET UX	4/3/2010	TARRANT	D210079049
TX	TARRANT	TX4390996.99	VICTOR P HARRISON ET UX	4/3/2010	TARRANT	D210079050
TX	TARRANT	TX4390997.00	BOOKER JOHNSON ET UX	2/1/2010	TARRANT	D210057851
TX	TARRANT	TX4390997.00	BOOKER JOHNSON ET UX	2/1/2010	TARRANT	D210156106
TX	TARRANT	TX4391002.99	RAYMOND ROSCOE CHANCE JR	4/13/2010	TARRANT	D210086539
TX	TARRANT	TX4391003.99	DENISE ANNETTE FOUCHEY GWINN	4/3/2010	TARRANT	D210086541
TX	TARRANT	TX4391004.99	JAMES RAEGAN DAVIS ET AL	4/3/2010	TARRANT	D210086538
TX	TARRANT	TX4391005.99	RICHARD CARTER JR ET AL	4/2/2010	TARRANT	D210086537

Exhibit A Page 13

PORTIONS OF THIS EXHIBIT DENOTED WITH THREE ASTERISKS (***) HAVE BEEN OMITTED PURSUANT TO A REQUEST FOR CONFIDENTIAL TREATMENT

TX	TARRANT	TX4391006.99	ROSEMARY L CHANCE ALBRIGHT	4/13/2010	TARRANT	D210086540
TX	TARRANT	TX4391008.00	ROBERT A BRODE ET UX	7/1/2010	TARRANT	D210250698
TX	TARRANT	TX4391010.00	ST TX MF-110644	3/23/2010	TARRANT	D210086560
TX	TARRANT	TX4391017.00	LOUIS F AKA LUIS RUIZ ET UX	5/11/2010	TARRANT	D210114850
TX	TARRANT	TX4391017.99	CITY OF FT WORTH	8/9/2010	TARRANT	D210198703
TX	TARRANT	TX4391018.99	CITY OF FT WORTH	8/4/2010	TARRANT	D210198705
TX	TARRANT	TX4391020.00	CITY OF FORT WORTH	5/18/2010	TARRANT	D210129774
TX	TARRANT	TX4391029.99	MORROW FAMILY TRUST 8-10-92	6/28/2010	TARRANT	D210156105
TX	TARRANT	TX4391031.00	BILLIE JOYCE PERRY INDIV AND EXEC	6/3/2010	TARRANT	D210134912
TX	TARRANT	TX4391035.00	BOOKER JOHNSON ET UX	6/17/2010	TARRANT	D210156106
TX	TARRANT	TX4391075.00	LEWIS & ASSOC REALTORS	9/17/2010	TARRANT	D210232350
TX	TARRANT	TX4391091.00	FT WORTH TERMINALS LLC	8/17/2010	TARRANT	D210262808
TX	TARRANT	TX4391092.00	CROWN ENTERPRISES INC	8/17/2010	TARRANT	D210262807
TX	TARRANT	TX4391182.00	ERNEST THOMAS ET UX	11/22/2010	TARRANT	D211006602
TX	TARRANT	TX4391187.00	DON VALK	12/30/2010	TARRANT	D211001528
TX	TARRANT	TX4391189.00	ERNEST THOMAS ET UX	11/23/2010	TARRANT	D211006601
TX	TARRANT	TX4391233.00	LINDA L ATKINS	1/6/2011	TARRANT	D211024558
TX	TARRANT	TX4391239.00	SCOTT R DAVIDSON	1/6/2011	TARRANT	D211024560
TX	TARRANT	TX4391253.00	MIKE MURRAY ET UX	2/3/2011	TARRANT	D211044528
TX	TARRANT	TX4391256.99	JUAN HERNANDEZ	12/20/2010	TARRANT	D210319282
TX	TARRANT	TX4391262.00	GDF PROPERTIES	3/30/2011	TARRANT	D211075997
TX	TARRANT	TX4391285.01	KEITH & KIMBERLY HAMPTON	6/2/2011	TARRANT	D211141700
TX	TARRANT	TX4391285.02	SANDRA SMITH	6/2/2011	TARRANT	D211141699
TX	TARRANT	TX4391300.01	DAVID ORTIZ ROMERO	8/12/2011	TARRANT	D211212308
TX	TARRANT	TX4391360.99	VANTAGE FORT WORTH ENERGY LLC	4/26/2013	TARRANT
TX	TARRANT	TX4391361.01	WILLIAM HORACE ANDERTON	1/2/2013	TARRANT	D213019851
TX	TARRANT	TX4391361.02	DAVID RAY ANDERTON	12/27/2012	TARRANT	D213019853
TX	TARRANT	TX4391361.03	RICHARD ANDERTON JR	12/27/2012	TARRANT	D213019852

Exhibit A Page 14

PORTIONS OF THIS EXHIBIT DENOTED WITH THREE ASTERISKS (***) HAVE BEEN OMITTED PURSUANT TO A REQUEST FOR CONFIDENTIAL TREATMENT

EXHIBIT B

to the

GAS GATHERING AGREEMENT

This Exhibit B is attached to the Gas Gathering Agreement (the "Agreement") dated effective April 1, 2016 by and between BlueStone Natural Resources II, LLC, as Producer, and Cowtown Pipeline Partners L.P., as Gatherer, and made a part thereof for all purposes. All defined terms used herein shall have the same meaning as set forth in the Agreement.

Gathering System Receipt Point(s)

Ownership	Sales Meter Name	Meter #	Active?
CMLP/QRI	BLAIR EAST 1H	TX35976	Active
CMLP/QRI	BLAIR EAST 2H	TX34017	Active
CMLP/QRI	BLAIR EAST 3H	TX34015	Active
CMLP/QRI	BLAIR EAST 4H	TX34018	Active
CMLP/QRI	BLAIR EAST 5H	TX35975	Active
CMLP	BOSWELL NORTH 1-9 SALES	TX20426	Active
CMLP	BOSWELL SOUTH SALES	TX20975	Active
CMLP/QRI	CITY OF ARLINGTON 1H	TX32737	Active
CMLP/QRI	CITY OF ARLINGTON 2H	TX32738	Active
CMLP/QRI	CITY OF ARLINGTON 3H	TX32739	Active
CMLP/QRI	CITY OF ARLINGTON 4H	TX32740	Active
CMLP/QRI	CITY OF ARLINGTON 5H	TX32741	Active
CMLP/QRI	CITY OF ARLINGTON 6H	TX32742	Active
CMLP/QRI	CITY OF ARLINGTON 7H	TX33814	Active
CMLP/QRI	CITY OF ARLINGTON 8H	TX33807	Active
CMLP/QRI	CITY OF ARLINGTON 9H	TX33808	Active
CMLP/QRI	CITY OF ARLINGTON 10H	TX33809	Active
CMLP/QRI	CITY OF ARLINGTON 11H	TX33810	Active
CMLP/QRI	CITY OF ARLINGTON 12H	TX33811	Active
CMLP/QRI	CITY OF ARLINGTON 14H	TX33813	Active
CMLP	DUKE SALES	TX50001	Active
CMLP	EXELON NORTH SALES	TX20616	Active
CMLP/QRI	EXELON SOUTH 1H	TX32730	Active
CMLP/QRI	EXELON SOUTH 2H	TX32731	Active
CMLP	EXELON SOUTH 3H	TX32732	Active
CMLP/QRI	EXELON SOUTH 4H	TX32733	Active
CMLP/QRI	EXELON SOUTH 6H	TX32735	Active

Exhibit B Page 1

PORTIONS OF THIS EXHIBIT DENOTED WITH THREE ASTERISKS (***) HAVE BEEN OMITTED PURSUANT TO A REQUEST FOR CONFIDENTIAL TREATMENT

Ownership	Sales Meter Name	Meter #	Active?
CMLP/QRI	EXELON SOUTH 7H	TX33912	Active
CMLP/QRI	EXELON SOUTH 8H	TX33934	Active
CMLP/QRI	EXELON SOUTH 9H	TX33935	Active
CMLP	EXELON SOUTH 10H	TX33936	Active
CMLP/QRI	EXELON SOUTH 12H	TX33938	Active
CMLP	LAWHON SOUTH UNIT 2H	TX34086	Active
CMLP/QRI	LAWHON SOUTH UNIT 5H	TX34087	Active
CMLP/QRI	LAWHON SOUTH UNIT 7H	TX34071	Active
CMLP/QRI	LAWHON SOUTH UNIT 10H	TX34051	Active
CMLP/QRI	LAWHON SOUTH UNIT 11H	TX34058	Active
CMLP/QRI	LAWHON SOUTH UNIT 12H	TX34053	Active
CMLP/QRI	LAWHON SOUTH UNIT 13H	TX34052	Active
CMLP/QRI	LAWHON SOUTH UNIT 1H	TX34072	Active
CMLP	LAWHON WEST UNIT 2H	TX34861	Active
CMLP/QRI	MARTIN 820 1H	TX32000	Active
CMLP	MARTIN 820 3H	TX33416	Active
CMLP/QRI	MARTIN 820 4H	TX33392	Active
CMLP	MARTIN 820 5H	TX33393	Active
CMLP/QRI	MARTIN 820 6H	TX33396	Active
CMLP	OLCOTT NORTH A SALES	TX21004	Active
CMLP	OLCOTT SOUTH SALES	TX20673	Active
CMLP/QRI	SOUTH LOOP 820 1H	TX33664	Active
Texas Midstream (Williams)	VILLAGE CREEK PAD CRP	22421	Active
CMLP/QRI	WHIZ Q EAST UNIT 5H	TX34303	Active
CMLP/QRI	WHIZ Q EAST UNIT 11H	TX34808	Active
CMLP/QRI	WHIZ Q EAST UNIT 12H	TX34802	Active
CMLP/QRI	WHIZ Q WEST UNIT 5H	TX35056	Active
CMLP/QRI	WHIZ Q WEST UNIT 6H	TX35051	Active
CMLP/QRI	DUKE UNIT 1H	TX33219	Inactive
CMLP/QRI	LAWHON WEST UNIT 1H	TX34860	Inactive
CMLP	LAWHON WEST UNIT 3H	TX34862	Inactive
CMLP	MARTIN 820 2H	TX32010	Inactive
CMLP/QRI	WHIZ Q WEST UNIT 4H	TX35052	Inactive

Delivery Point(s) to Transporter

Exhibit B Page 2

PORTIONS OF THIS EXHIBIT DENOTED WITH THREE ASTERISKS (***) HAVE BEEN OMITTED PURSUANT TO A REQUEST FOR CONFIDENTIAL TREATMENT

Delivery Point	Transporter	Meter
Handley Quicksilver	Energy Transfer Fuel, LP	#009783

Exhibit B Page 3

PORTIONS OF THIS EXHIBIT DENOTED WITH THREE ASTERISKS (***) HAVE BEEN OMITTED PURSUANT TO A REQUEST FOR CONFIDENTIAL TREATMENT

EXHIBIT C

to the

GAS GATHERING AGREEMENT

This Exhibit C is attached to the Gas Gathering Agreement (the "Agreement") dated effective April 1, 2016 by and between BlueStone Natural Resources II, LLC, as Producer, and Cowtown Pipeline Partners L.P., as Gatherer, and made a part thereof for all purposes. All defined terms used herein shall have the same meaning as set forth in the Agreement.

Third Party Gatherer’s Receipt Point:

Village Creek Pad – Access Meter #22421

Third Party Delivery Point(s):

Delivery Point	Description	Meter
Crestwood Offload Point	Offload point between Third Party Gatherer and Gatherer’s Gathering System	TX20542
ETC Delivery Point	Mercado ETC Del	OMV10115
ETC Delivery Point	4th Street ETC Del	OMV10271
ETC Delivery Point	Delga ETC Del	OMV10107

Exhibit C Page 1

3230483v2

PORTIONS OF THIS EXHIBIT DENOTED WITH THREE ASTERISKS (***) HAVE BEEN OMITTED PURSUANT TO A REQUEST FOR CONFIDENTIAL TREATMENT

EXHIBIT D

to the

GAS GATHERING AGREEMENT

This Exhibit D is attached to the Gas Gathering Agreement (the "Agreement") dated effective April 1, 2016 by and between BlueStone Natural Resources II, LLC, as Producer, and Cowtown Pipeline Partners L.P., as Gatherer, and made a part thereof for all purposes. All defined terms used herein shall have the same meaning as set forth in the Agreement.

AREA	WELL
BARNETT LA	BLAIR EAST UNIT 4H
BARNETT LA	EXELON NORTH 13H
BARNETT LA	EXELON SOUTH 10H
BARNETT LA	EXELON SOUTH 3H
BARNETT LA	EXELON SOUTH 8H
BARNETT LA	LAWHON SOUTH UNIT 13H
BARNETT LA	WHIZ Q WEST UNIT 5H
BARNETT LA	WHIZ Q WEST UNIT 6H

Exhibit D Page 1

3230483v2

EX-10.6

PORTIONS OF THIS EXHIBIT DENOTED WITH THREE ASTERISKS (***) HAVE BEEN OMITTED PURSUANT TO A REQUEST FOR CONFIDENTIAL TREATMENT

EXHIBIT 10.6

By Email

April 6, 2016

John Redmond

President/Chief Executive Officer

BlueStone Natural Resources II, LLC

2100 South Utica, Suite 200
Tulsa, OK 74114

jredmond@bluestone-nr.com

Re:    Letter Agreement to Gathering and Processing Agreements

John:

Reference is hereby made to that certain (a) Gas Gathering Agreement, dated as of April 1, 2016, among Cowtown Pipeline Partners LP (“Cowtown Pipeline”), as Gatherer, and BlueStone Natural Resources II, LLC (“Buyer”), as Producer, for the Alliance area (the “New Alliance GGA”); (b) Gas Gathering and Processing Agreement, dated as of April 1, 2016, among Buyer, as Producer, Cowtown Pipeline, as Gatherer, and Cowtown Gas Processing Partners LP (“Cowtown Processing,” together with Cowtown Pipeline, “CMLP”), as Processor, for the Cowtown area (the “New Cowtown GGPA”); and (c) Gas Gathering Agreement, dated as of April 1, 2016, among Buyer, as Producer, and Cowtown Pipeline, as Gatherer, for the Lake Arlington area (the “New Lake Arlington GGA”, and together with the New Alliance GGA and the New Cowtown GGPA, the “BlueStone Gathering Agreements”). Whereas Buyer has agreed to acquire the Dedicated Properties formerly owned by Quicksilver Resources Inc. (“QRI”), Buyer and CMLP desire to set forth certain agreements related to Dedicated Properties and the gathering and processing of natural gas therefrom as memorialized in this letter agreement (“Letter Agreement”). This Letter Agreement is being executed contemporaneously with the BlueStone Gathering Agreements. Buyer and CMLP represent, warrant, and agree the BlueStone Gathering Agreements and Letter Agreement collectively comprise one transaction. Buyer and CMLP are each referred to individually as a “Party” and collectively as the “Parties”. Fully executed copies of the BlueStone Gathering Agreements are attached as Exhibit A to this Letter Agreement. Capitalized terms used but not otherwise defined herein shall have the meanings set forth in the BlueStone Gathering Agreements.

1. Gathering Agreements; Bankruptcy Process.

a. The BlueStone Gathering Agreements shall exclusively govern the gathering by Gatherer and processing by Processor of the Subject Gas in the Dedicated Properties, except for any natural gas owned by TG Barnett Resources LLC (“Tokyo Gas”). Buyer acknowledges it is aware of the following agreements: (a) Gas Gathering Agreement, dated as of December 1, 2009, among Cowtown Pipeline, as Gatherer and successor to Cowtown Pipeline LP, and QRI and Tokyo Gas, collectively, as Producer, (as amended, modified or otherwise supplemented, the “Alliance GGA”), (b) Sixth Amended and Restated Gas Gathering and Processing Agreement, dated as of September 1, 2008, among QRI and Tokyo Gas,

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PORTIONS OF THIS EXHIBIT DENOTED WITH THREE ASTERISKS (***) HAVE BEEN OMITTED PURSUANT TO A REQUEST FOR CONFIDENTIAL TREATMENT

collectively, as Producer, Cowtown Pipeline, as Gatherer, and Cowtown Processing, as Processor (as amended, modified or otherwise supplemented, the “Cowtown GGPA”), and (c) Amended and Restated Gas Gathering Agreement, dated as of September 1, 2008, among Cowtown Pipeline, as Gatherer, and QRI and Tokyo Gas, collectively, as Producer (as amended, modified or otherwise supplemented, the “Lake Arlington GGA”, and together with the Alliance GGA and the Cowtown GGPA, the “Tokyo Gas Gathering Agreements”).

b. Contemporaneously with the “Closing” on the sale of “Oil and Gas Assets” as defined in that certain Asset Purchase Agreement by and among QRI, Cowtown Gas Processing L.P. and Cowtown Pipeline L.P. and Buyer, dated January 22, 2016 (“Asset Purchase Agreement”), QRI will file with the U.S. Bankruptcy Court for the District of Delaware (“Bankruptcy Court”) in Case No. 15-10585 a withdrawal with prejudice (the “Notice of Withdrawal”) of QRI’s “Motion for an Order Authorizing and Approving Rejection of Certain Executory Contracts with Affiliates of Crestwood Midstream Partners LP” dated February 5, 2016, which Notice of Withdrawal shall be effective upon filing.

c. The BlueStone Gathering Agreements shall each become effective and binding upon the Parties thereto upon the occurrence of the “Triggering Event” (as defined in the Closing Agreement dated April 6, 2016, among Buyer, CMLP, Quicksilver Resources, Inc., Cowtown Gas Processing L.P. and Cowtown Pipeline L.P). Subject to the Closing occurring on or before April 15, 2016, the “Effective Date” under each of the BlueStone Gathering Agreements shall be April 1, 2016.

2. Other Agreements/Arrangements. In connection with the transactions contemplated by the BlueStone Gathering Agreements, the Parties hereby undertake the following on the terms and conditions as set forth and specified below:

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PORTIONS OF THIS EXHIBIT DENOTED WITH THREE ASTERISKS (***) HAVE BEEN OMITTED PURSUANT TO A REQUEST FOR CONFIDENTIAL TREATMENT

POLA; Conveyance of Assets to CMLP The Parties acknowledge and agree that Buyer shall assume as modified herein that certain Pipeline Operating and License Agreement for the Cowtown Laterals dated as of September 1, 2009, by and between Cowtown Pipeline, and Cowtown Pipeline L.P. (the “POLA”) without any cure cost. The POLA shall be modified so its term shall expire six (6) months after the Effective Date (which term the Parties may mutually agree to terminate or extend) (the “Cowtown Laterals Option Period”). Buyer shall be entitled to the rights and obligated to perform the duties of “Owner” and CMLP shall be entitled to the rights and obligated to perform the duties of “Operator” as defined in the POLA. Upon CMLP’s completion of its due diligence and election to proceed with the acquisition of the Cowtown Laterals (as defined in the POLA) specified in Exhibit B hereto no later than the end of the Cowtown Laterals Option Period, Buyer shall convey to CMLP, subject to any existing legal or contractual impediment and to the Parties’ using commercially reasonable efforts to enter into definitive agreements, all of its right, title and interest in those Cowtown Laterals for (***) on customary terms and conditions for an “as is,” “where is” transaction. In addition, Buyer and CMLP shall enter into good faith negotiations regarding the conveyance to CMLP of any remaining Cowtown Laterals for (***) on customary terms and conditions for an “as is,” “where is” transaction. Upon completion of the foregoing transaction, CMLP shall assume operations and maintenance responsibilities for the conveyed pipelines in accordance with the existing terms and fees in the BlueStone Gathering Agreements. If any Cowtown Laterals are not acquired by CMLP pursuant to the foregoing transactions, the Parties shall cooperate in good faith to determine the need for provisions of the POLA to survive beyond the Cowtown Laterals Option Period pursuant to mutual agreement.

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PORTIONS OF THIS EXHIBIT DENOTED WITH THREE ASTERISKS (***) HAVE BEEN OMITTED PURSUANT TO A REQUEST FOR CONFIDENTIAL TREATMENT

JOA; SCADA The Parties acknowledge and agree that Buyer shall assume as modified herein that certain Joint Operating Agreement dated as of July 1, 2010, by and between QRI, Quicksilver Gas Services LP, and Quicksilver Gas Services GP LLC (the “JOA”) without any cure cost. The JOA shall be modified so its term shall expire ninety (90) days after the Effective Date (which term the Parties may mutually agree to terminate or extend) (the “JOA Extension Period”). During the JOA Extension Period, the Parties shall perform under Articles 1, 3, 4, 5, 6 and 7 of the JOA, but the remainder of such JOA shall no longer be applicable, and Buyer shall be entitled to the rights and obligated to perform the duties of “KWK” and CMLP shall be entitled to the rights and obligated to perform the duties of “KGS” as defined in the JOA. (a) During the JOA Extension Period, the Parties shall negotiate in good faith to enter into an agreement that provides for access, utilization, and sharing of information accessed through the SCADA infrastructure as it relates to CMLP for the Cowtown, Alliance and Lake Arlington systems (“CMLP Systems”), and Buyer for the assets acquired through the Asset Purchase Arrangement (“SCADA Agreement”). The objective of the SCADA Agreement is to create a mutually beneficial arrangement that provides Buyer and Seller with the requisite access, information, and control to operate, maintain, and manage their respective assets, including CMLP’s ability to operate the CMLP System for service to third parties. (b) To the extent Buyer and CMLP are not able to come to mutually agreeable terms for the SCADA Agreement, and subject to Buyer’s ability to secure the necessary third party software licenses and governmental communication licenses for its own production operation, the Parties will default to a structure where CMLP has access to the requisite SCADA infrastructure and information to manage and operate the CMLP Systems to provide service to Buyer, as it relates to the BlueStone Gathering Agreements, and third parties, as it relates to any current or future gas gathering or processing agreements, in a manner consistent with how CMLP currently accesses SCADA for information for its custody transfer measurement into the CMLP Systems (“Default SCADA Structure”). For the avoidance of doubt, the Default SCADA Structure shall not include those remote terminal units, process logic controllers, pressure transmitters, actuators or electronic flow measurement devices that are located on well pad facilities and are used exclusively for Buyer’s production operations. The Default SCADA Structure will provide for CMLP to access the existing system using a Citrix front end, or similar technology that Buyer elects to employ, that allows access for the CygNet system. The data accessed through the Default SCADA Structure will include but not be limited to current readings, alarm values, set points, history, and audit information. CMLP users will be granted administration rights to CygNet including the Gas Meter Repository (“GMR”). The CygNet server will be maintained by Buyer as well as the communications infrastructure and any connection used to collect data from towers. Currently, the electronic flow computer (“EFM”) equipment is tested, calibrated, and sampled by CMLP with reimbursement provided by Buyer for any of Buyer’s EFM equipment maintained by CMLP. However, to the extent Buyer takes control of maintenance of its EFM equipment such reimbursement to CMLP will cease, as applicable. CMLP shall reimburse Buyer for forty percent (40%) of the actual operating expenses incurred by Buyer for licensing as it relates to forward software maintenance costs specifically for the mutual SCADA host and associated drivers, and maintenance of the Default SCADA Structure (“SCADA Costs”). SCADA Costs will be limited to the prudently incurred direct costs, including labor, software licensing, parts, materials and allocated first level supervision by Buyer to maintain (a) the SCADA hosts and directly associated computer and directly connected networking equipment, (b) the communication infrastructure including all third party data circuits that are specific to each field point of presence (i.e., tower), government licenses and radio infrastructure, and (c) the on-site communication, generally being the local radio or modem and associated antenna and support, necessary to provide the services describe above. For the avoidance of doubt, reimbursements by CMLP will not be required for anything that does not directly relate to the Default SCADA Structure. Reimbursements by CMLP will be required for equipment when replaced with in-kind equipment or upgrades to which CMLP consents in writing. Buyer will invoice CMLP for SCADA Costs on a monthly basis and CMLP agrees to make payment within thirty (30) days of receipt of any such invoice. Any costs associated with the repair, replacement or calibration of SCADA infrastructure that is not considered to be part of the Default SCADA Structure will be the responsibility of the owner of such infrastructure. Buyer and CMLP shall enter into good faith negotiations regarding the conveyance to CMLP of the Alliance and Lake Arlington gas lift systems for (***) on customary terms and conditions for an “as is,” “where is” transaction. Upon completion of the foregoing transaction, CMLP shall assume operations and maintenance responsibilities for the conveyed pipelines and provide Gas Lift service in accordance with the existing terms and fees in the BlueStone Gathering Agreements. If any Gas Lift pipelines are not acquired by CMLP pursuant to the foregoing transaction, the Parties shall cooperate in good faith to determine the need for the above specified provisions of the JOA to survive the JOA Extension Period pursuant to mutual agreement.

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PORTIONS OF THIS EXHIBIT DENOTED WITH THREE ASTERISKS (***) HAVE BEEN OMITTED PURSUANT TO A REQUEST FOR CONFIDENTIAL TREATMENT

3. Scope of Obligations. The BlueStone Gathering Agreements are intended to be agreements of the Parties with respect to the subject matter thereof, and it is understood that this Letter Agreement is intended to, and does, create a legally binding agreement on the part of each Party as expressly set forth in Section 2, subject to any existing legal or contractual impediment. For the avoidance of doubt, the Parties acknowledge and agree that (a) the natural gas owned by Tokyo Gas is subject to the Tokyo Gas Gathering Agreements (including the fees set forth therein) and may be delivered to CMLP by Buyer pursuant to a joint operating agreement between Buyer and Tokyo Gas, (b) Buyer is not bound by the Tokyo Gas Gathering Agreements in any respect, and (c) the Tokyo Gas Gathering Agreements shall have no force and effect with respect to the Dedicated Properties.

4. Confidentiality. No Party shall directly or indirectly communicate or disclose (whether orally, in writing or otherwise) to any third party (other than their respective directors, officers, representatives, agents, members, potential financing sources, ratings agencies, professional advisors, attorneys and employees, in their capacity as such, “Representatives”) any information with respect to the terms of this Letter Agreement or the BlueStone Gathering Agreements or the ongoing negotiations in connection with this Letter Agreement or the BlueStone Gathering Agreements, except: (a) to the extent necessary to comply with law or the valid order of a court of competent jurisdiction, in which event the party making such disclosure shall, to the extent practicable, so notify the other and shall seek confidential treatment of such information; (b) as part of its normal reporting or review procedure to its parent company and affiliates, its partners, its members, its financing sources, its accountants, its auditors and its attorneys; (c) in order to enforce its rights pursuant to this Letter Agreement in a legal proceeding; and (d) as otherwise consented to by the other Parties. Each Party shall be responsible for any breach by its Representatives of their confidentiality obligations. No Party shall make any public announcement or press release regarding the contents of this Letter Agreement, including, without limitation, without the prior written consent of the other Parties, which consent shall be given or withheld in each Party’s sole discretion. The content of any public announcement or press release must be approved by all Parties. For the avoidance of doubt, following execution of this Letter Agreement a Party may issue one or more press releases, to the extent required in its reasonable discretion by disclosure requirements, describing the execution of this Letter Agreement and the BlueStone Gathering Agreements, the filing of the Notice of Withdrawal, and the Closing and Effective Date, by first providing a draft to the other Party with opportunity for comment.

5. Miscellaneous.

a.
Nothing in this Letter Agreement is intended to, nor shall it, modify the BlueStone Gathering Agreements or the Tokyo Gas Gathering Agreement in any manner, which shall continue to be binding in accordance with the terms thereof.

b.
All costs and expenses incurred in connection with this Letter Agreement, including attorneys’ fees, shall be borne by the Party that incurred such costs or expenses.

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PORTIONS OF THIS EXHIBIT DENOTED WITH THREE ASTERISKS (***) HAVE BEEN OMITTED PURSUANT TO A REQUEST FOR CONFIDENTIAL TREATMENT

c.
This Letter Agreement sets out the Parties’ entire understanding on those matters set forth in Section 2 as of the date hereof, and there are no other written or oral agreements or understandings among the Parties with respect to the subject matter. The Parties warrant and represent that no promise, agreement, representation, inducement, or condition which is not herein expressed has been made to either Party by the other, or any agent or representative of either Party to the other, in executing this Letter Agreement.  The Parties further warrant and represent they are not relying upon, and expressly disclaim, any such promise, agreement, representation, inducement, or condition which is not herein expressed in executing this Letter Agreement. The Parties represents and warrant they are relying solely upon their own judgment in entering this Letter Agreement.

d.
This Letter Agreement may be executed in one or more counterparts delivered in .pdf or other electronic format, each of which shall be deemed an original, but all of which together will be considered one and the same agreement, and will become effective when one or more such counterparts have been signed by each of the Parties and delivered to each Party.

e.
This Letter Agreement shall be governed by and construed in accordance with the laws of the State of Texas, without regard to the choice of law rules thereof that would result in the application of the laws of any other jurisdiction. Each of the Parties hereto consents to the exclusive jurisdiction of the state and federal courts within the State of Texas, County of Harris over all matters related to this Letter Agreement and with respect to any dispute arising under this Letter Agreement, and to the service of process in any manner provided by law. IN ANY SUIT FILED BY A PARTY HERETO TO RESOLVE A DISPUTE ARISING UNDER THIS LETTER AGREEMENT, EACH PARTY HEREBY COVENANTS AND AGREES TO TAKE ALL STEPS NECESSARY TO WAIVE TRIAL BY JURY. IN NO EVENT WILL EITHER PARTY HAVE LIABILITY TO THE OTHER PARTY FOR, AND EACH PARTY HEREBY IRREVOCABLY WAIVES, REMOTE OR INDIRECT CONSEQUENTIAL LOSSES OR DAMAGES, OR PUNITIVE OR EXEMPLARY DAMAGES, INCLUDING, BUT NOT LIMITED TO, LOSS OF REVENUE AND LOSS OF ANTICIPATED PROFIT (EXCEPT TO THE EXTENT SUCH LOSS OF REVENUE OR ANTICIPATED PROFIT IS ALSO DIRECT, ACTUAL DAMAGES), IRRESPECTIVE OF WHETHER THE LOSSES OR DAMAGES WERE FORESEEABLE, RESULTING FROM OR ARISING OUT OF THE PERFORMANCE, DEFECTIVE PERFORMANCE OR NON-PERFORMANCE BY ANY OR ALL OF THE PARTIES OF ITS OR THEIR OBLIGATION(S) UNDER THIS GATHERING AGREEMENTS, OR THE RESULT OF THE SOLE, ACTIVE, PASSIVE, CONCURRENT OR COMPARATIVE NEGLIGENCE, STRICT LIABILITY, BREACH OF DUTY (STATUTORY OR OTHERWISE), OR OTHER FAULT OF OR VIOLATION OF ANY LAW OF THE PARTY WHOSE LIABILITY IS BEING WAIVED. The Parties

- 6 -

PORTIONS OF THIS EXHIBIT DENOTED WITH THREE ASTERISKS (***) HAVE BEEN OMITTED PURSUANT TO A REQUEST FOR CONFIDENTIAL TREATMENT

have participated jointly in the negotiation and drafting of this Letter Agreement. In the event an ambiguity or question of intent or interpretation arises, this Letter Agreement will be construed as if drafted jointly by the Parties, and no presumption or burden of proof will arise favoring or disfavoring any Party by virtue of the authorship of any of the provisions of this Letter Agreement. Neither Party may assign any right or obligation under this Letter Agreement without the prior written consent of the other Party. Nothing in this Letter Agreement, expressed or implied, will give or be construed to give any person, other than the Parties and their successors and permitted assigns, any legal or equitable right, remedy or claim under or in respect of this Letter Agreement or under any covenant, condition, or provision contained in this Letter Agreement; and all such covenants, conditions, and provisions will be for the sole benefit of the Parties. This Section 5(e) shall survive expiration or termination of this Letter Agreement for purposes of any dispute arising hereunder.

f.
Exhibit A is attached and made part of this Letter Agreement.

- 7 -

PORTIONS OF THIS EXHIBIT DENOTED WITH THREE ASTERISKS (***) HAVE BEEN OMITTED PURSUANT TO A REQUEST FOR CONFIDENTIAL TREATMENT

If the foregoing is agreeable to BlueStone Natural Resources II, LLC, please execute below and return to my attention.

Very truly yours,

Acknowledged and agreed to by the Parties as of the date first written above:

Cowtown Pipeline Partners L.P. By: Crestwood Gas Services Operating GP LLC, its general partner By: Heath Deneke ________ ______ Name: Heath Deneke Title: Chief Operating Officer and President, Pipeline Services Group Cowtown Gas Processing Partners L.P. By: Crestwood Gas Services Operating GP LLC, its general partner By: Heath Deneke ________ ______ Name: Heath Deneke Title: Chief Operating Officer and President, Pipeline Services Group BlueStone Natural Resources II, LLC By:_ John Redmond ______________ Name: John Redmond Title: President/Chief Executive Officer

- 8 -

PORTIONS OF THIS EXHIBIT DENOTED WITH THREE ASTERISKS (***) HAVE BEEN OMITTED PURSUANT TO A REQUEST FOR CONFIDENTIAL TREATMENT

EXHIBIT A – BLUESTONE GATHERING AGREEMENTS

[Exhibit A to Letter Agreement to Gathering Agreements]

PORTIONS OF THIS EXHIBIT DENOTED WITH THREE ASTERISKS (***) HAVE BEEN OMITTED PURSUANT TO A REQUEST FOR CONFIDENTIAL TREATMENT

EXHIBIT B – COWTOWN LATERALS TO BE CONVEYED

North West 12”	~80,735 feet	15.3 miles
North West 20”	~92,880 feet	17.6 miles
Hill County 20”	~27,500 feet	5.2 miles

MAP

(Line Segments Highlighted Below)

(***)

[Exhibit B to Letter Agreement to Gathering Agreements]

EX-12.1

Exhibit 12.1

CRESTWOOD EQUITY PARTNERS LP

COMPUTATION OF RATIO OF EARNINGS TO FIXED CHARGES

(in millions, except for ratio)

	Three Months Ended June 30,						Six Months Ended June 30,
	2016			2015			2016			2015
Earnings:
Pre-tax loss from continuing operations before adjustment for non-controlling interest and equity earnings (including amortization of excess cost of equity investment) per statements of income	$	(43.3	)	$	(301.3	)	$	(143.5	)	$	(286.2	)
Add:
Fixed charges	35.6			39.8			75.0			77.7
Amortized capitalized interest	0.1			0.1			0.2			0.1
Distributed income of equity investees	6.3			6.4			11.9			6.4
Less:
Capitalized interest	(0.2		)	(0.9		)	(0.5		)	(1.6		)
Non-controlling interest in pre-tax income of subsidiary with no fixed charges	(6.0		)	(5.7		)	(11.9		)	(11.3		)
Total earnings available for fixed charges	$	(7.5	)	$	(261.6	)	$	(68.8	)	$	(214.9	)
Fixed charges:
Interest and debt expense	34.5			36.3			70.9			70.6
Interest component of rent	1.1			3.5			4.1			7.1
Total fixed charges	$	35.6		$	39.8		$	75.0		$	77.7
Ratio of earnings to fixed charges (1) (2)	—			—			—			—

(1) For purposes of computing the ratio of earnings to fixed charges, "earnings" consists of pretax income from continuing operations before adjustment for non-controlling interest and income from equity investee plus fixed charges (excluding capitalized interest) and amortized capitalized interest. "Fixed charges" represents interest incurred (whether expensed or capitalized), amortization of debt costs and that portion of rental expense on operating leases deemed to be the equivalent of interest.

(2) Earnings for the three and six months endedJune 30, 2016 were inadequate to cover fixed charges by approximately $43.1 million and $143.8 million. Earnings for the three and six months ended June 30, 2015 were inadequate to cover fixed charges by approximately $301.4 million and $292.6 million.

EX-12.2

Exhibit 12.2

CRESTWOOD MIDSTREAM PARTNERS LP

COMPUTATION OF RATIO OF EARNINGS TO FIXED CHARGES

(in millions, except for ratio)

	Three Months Ended June 30,								Six Months Ended June 30,
	2016				2015				2016				2015
Earnings:
Pre-tax loss from continuing operations before adjustment for non-controlling interest and equity earnings (including amortization of excess cost of equity investment) per statements of income	$	(41.6	)		$	(77.7	)		$	(143.6	)		$	(51.6	)
Add:
Fixed charges	35.6				37.0				75.0				71.2
Amortized capitalized interest	0.1				0.1				0.2				0.1
Distributed income of equity investees	6.3				6.4				11.9				6.4
Less:
Capitalized interest	(0.2		)		(0.9		)		(0.5		)		(1.6		)
Non-controlling interest in pre-tax income of subsidiary with no fixed charges	(6.0		)		(5.7		)		(11.9		)		(11.3		)
Total earnings available for fixed charges	$	(5.8	)		$	(40.8	)		$	(68.9	)		$	13.2
Fixed charges:
Interest and debt expense	34.5				33.5				70.9				64.1
Interest component of rent	1.1				3.5				4.1				7.1
Total fixed charges	$	35.6			$	37.0			$	75.0			$	71.2
Ratio of earnings to fixed charges(1)	—			(2)	—			(2)	—			(2)	0.2

(1) For purposes of computing the ratio of earnings to fixed charges, "earnings" consists of pretax income from continuing operations before adjustment for non-controlling interest and income from equity investee plus fixed charges (excluding capitalized interest) and amortized capitalized interest. "Fixed charges" represents interest incurred (whether expensed or capitalized), amortization of debt costs and that portion of rental expense on operating leases deemed to be the equivalent of interest.

(2) Earnings for the three and six months endedJune 30, 2016 were inadequate to cover fixed charges by $41.4 million and $143.9 million. Earnings for the three months ended June 30, 2015 were inadequate to cover fixed charges by approximately $77.8 million.

EX-31.1

Exhibit 31.1

CERTIFICATIONS

I, Robert G. Phillips, certify that:

1. I have reviewed this quarterly report on Form 10-Q of Crestwood Equity Partners LP (the “registrant”);

2. Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3. Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4. The registrant's other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d - 15(f)) for the registrant and have:

a. Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

b. Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

c. Evaluated the effectiveness of the registrant's disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

d. Disclosed in this report any change in the registrant's internal control over financial reporting that occurred during the registrant's most recent fiscal quarter (the registrant's fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant's internal control over financial reporting; and

5. The registrant's other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant's auditors and the audit committee of the registrant's board of directors (or persons performing the equivalent functions):

a. All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant's ability to record, process, summarize and report financial information; and

b. Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant's internal control over financial reporting.

Date: August 4, 2016

/s/ Robert G. Phillips

Robert G. Phillips

Chairman, President and Chief Executive Officer

EX-31.2

Exhibit 31.2

CERTIFICATIONS

I, Robert T. Halpin, certify that:

1. I have reviewed this quarterly report on Form 10-Q of Crestwood Equity Partners LP (the “registrant”);

2. Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3. Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4. The registrant's other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d - 15(f)) for the registrant and have:

a. Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

b. Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

c. Evaluated the effectiveness of the registrant's disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

d. Disclosed in this report any change in the registrant's internal control over financial reporting that occurred during the registrant's most recent fiscal quarter (the registrant's fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant's internal control over financial reporting; and

5. The registrant's other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant's auditors and the audit committee of the registrant's board of directors (or persons performing the equivalent functions):

a. All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant's ability to record, process, summarize and report financial information; and

b. Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant's internal control over financial reporting.

Date: August 4, 2016

/s/ Robert T. Halpin

Robert T. Halpin

Senior Vice President and Chief Financial Officer

EX-31.3

Exhibit 31.3

CERTIFICATIONS

I, Robert G. Phillips, certify that:

1. I have reviewed this quarterly report on Form 10-Q of Crestwood Midstream Partners LP (the “registrant”);

2. Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3. Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4. The registrant's other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d - 15(f)) for the registrant and have:

a. Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

b. Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

c. Evaluated the effectiveness of the registrant's disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

d. Disclosed in this report any change in the registrant's internal control over financial reporting that occurred during the registrant's most recent fiscal quarter (the registrant's fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant's internal control over financial reporting; and

5. The registrant's other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant's auditors and the audit committee of the registrant's board of directors (or persons performing the equivalent functions):

a. All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant's ability to record, process, summarize and report financial information; and

b. Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant's internal control over financial reporting.

Date: August 4, 2016

/s/ Robert G. Phillips

Robert G. Phillips

Chairman, President and Chief Executive Officer

EX-31.4

Exhibit 31.4

CERTIFICATIONS

I, Robert T. Halpin, certify that:

1. I have reviewed this quarterly report on Form 10-Q of Crestwood Midstream Partners LP (the “registrant”);

2. Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3. Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4. The registrant's other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d - 15(f)) for the registrant and have:

a. Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

b. Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

c. Evaluated the effectiveness of the registrant's disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

d. Disclosed in this report any change in the registrant's internal control over financial reporting that occurred during the registrant's most recent fiscal quarter (the registrant's fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant's internal control over financial reporting; and

5. The registrant's other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant's auditors and the audit committee of the registrant's board of directors (or persons performing the equivalent functions):

a. All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant's ability to record, process, summarize and report financial information; and

b. Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant's internal control over financial reporting.

Date: August 4, 2016

/s/ Robert T. Halpin    

Robert T. Halpin

Senior Vice President and Chief Financial Officer

EX-32.1

Exhibit 32.1

Certification of the Chief Executive Officer

Pursuant to 18 U.S.C. Section 1350

As Adopted Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002

In connection with the Quarterly Report of Crestwood Equity Partners LP (the “Company”) on Form 10-Q for the period ended June 30, 2016, as filed with the Securities and Exchange Commission on the date hereof (the “Report”), I, Robert G. Phillips, Chief Executive Officer of Crestwood Equity Partners LP, certify, pursuant to 18 U.S.C. § 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, that:

(1) The Report fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934; and

(2) The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Company.

	/s/ Robert G. Phillips
August 4, 2016	Robert G. Phillips Chief Executive Officer

A signed original of this written statement required by Section 906, or other document authenticating, acknowledging, or otherwise adopting the signature that appears in typed form within the electronic version of this written statement required by Section 906, has been provided to the Company and will be retained by the Company and furnished to the Securities and Exchange Commission or its staff upon request.

EX-32.2

Exhibit 32.2

Certification of the Chief Financial Officer

Pursuant to 18 U.S.C. Section 1350

As Adopted Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002

In connection with the Quarterly Report of Crestwood Equity Partners LP (the “Company”) on Form 10-Q for the period ended June 30, 2016, as filed with the Securities and Exchange Commission on the date hereof (the “Report”), I, Robert T. Halpin, Chief Financial Officer of Crestwood Equity Partners LP, certify, pursuant to 18 U.S.C. § 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, that:

(1) The Report fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934; and

(2) The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Company.

	/s/ Robert T. Halpin
August 4, 2016	Robert T. Halpin Chief Financial Officer

A signed original of this written statement required by Section 906, or other document authenticating, acknowledging, or otherwise adopting the signature that appears in typed form within the electronic version of this written statement required by Section 906, has been provided to the Company and will be retained by the Company and furnished to the Securities and Exchange Commission or its staff upon request.

EX-32.3

Exhibit 32.3

Certification of the Chief Executive Officer

Pursuant to 18 U.S.C. Section 1350

As Adopted Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002

In connection with the Quarterly Report of Crestwood Midstream Partners LP (the “Company”) on Form 10-Q for the period ended June 30, 2016, as filed with the Securities and Exchange Commission on the date hereof (the “Report”), I, Robert G. Phillips, Chief Executive Officer of Crestwood Midstream Partners LP, certify, pursuant to 18 U.S.C. § 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, that:

(1) The Report fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934; and

(2) The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Company.

	/s/ Robert G. Phillips
August 4, 2016	Robert G. Phillips Chief Executive Officer

A signed original of this written statement required by Section 906, or other document authenticating, acknowledging, or otherwise adopting the signature that appears in typed form within the electronic version of this written statement required by Section 906, has been provided to the Company and will be retained by the Company and furnished to the Securities and Exchange Commission or its staff upon request.

EX-32.4

Exhibit 32.4

Certification of the Chief Financial Officer

Pursuant to 18 U.S.C. Section 1350

As Adopted Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002

In connection with the Quarterly Report of Crestwood Midstream Partners LP (the “Company”) on Form 10-Q for the period ended June 30, 2016, as filed with the Securities and Exchange Commission on the date hereof (the “Report”), I, Robert T. Halpin, Chief Financial Officer of Crestwood Midstream Partners LP, certify, pursuant to 18 U.S.C. § 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, that:

(1) The Report fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934; and

(2) The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Company.

	/s/ Robert T. Halpin
August 4, 2016	Robert T. Halpin Chief Financial Officer

A signed original of this written statement required by Section 906, or other document authenticating, acknowledging, or otherwise adopting the signature that appears in typed form within the electronic version of this written statement required by Section 906, has been provided to the Company and will be retained by the Company and furnished to the Securities and Exchange Commission or its staff upon request.

XML

Document and Entity Information - shares	6 Months Ended
	Jun. 30, 2016	Jul. 29, 2016
Document Information [Line Items]
Document Type	10-Q
Amendment Flag	false
Document Period End Date	Jun. 30, 2016
Document Fiscal Year Focus	2016
Document Fiscal Period Focus	Q2
Trading Symbol	CEQP
Entity Registrant Name	Crestwood Equity Partners LP
Entity Central Index Key	0001136352
Current Fiscal Year End Date	--12-31
Entity Filer Category	Accelerated Filer
Entity Common Stock, Shares Outstanding		69,054,059
Crestwood Midstream Partners LP
Document Information [Line Items]
Document Type	10-Q
Amendment Flag	false
Document Period End Date	Jun. 30, 2016
Document Fiscal Year Focus	2016
Document Fiscal Period Focus	Q2
Entity Registrant Name	Crestwood Midstream Partners LP
Entity Central Index Key	0001304464
Current Fiscal Year End Date	--12-31
Entity Filer Category	Non-accelerated Filer
Entity Common Stock, Shares Outstanding		0

XML

Consolidated Balance Sheets - USD ($) $ in Millions	Jun. 30, 2016	Dec. 31, 2015
Assets
Cash	$ 0.9	$ 0.5
Accounts receivable	247.5	236.5
Inventory	43.5	44.5
Assets from price risk management activities	9.5	32.6
Assets Held-for-sale, Not Part of Disposal Group, Current	55.0	0.0
Prepaid expenses and other current assets	10.9	21.7
Total current assets	367.3	335.8
Property, plant and equipment	2,538.9	3,747.7
Less: accumulated depreciation and depletion	390.9	436.9
Property, plant and equipment, net	2,148.0	3,310.8
Intangible assets	946.8	975.8
Less: accumulated amortization	225.0	206.6
Intangible assets, net	721.8	769.2
Goodwill	249.5	1,085.5
Investment in unconsolidated affiliates (Note 4)	1,099.1	254.3
Other assets	7.7	7.2
Total assets	4,593.4	5,762.8
Current liabilities:
Accounts payable	164.5	144.1
Accrued expenses and other liabilities (Note 3)	101.2	105.6
Liabilities from price risk management activities	10.9	7.4
Current portion of long-term debt (Note 7)	0.9	1.1
Total current liabilities	277.5	258.2
Long-term debt, less current portion (Note 7)	1,581.6	2,501.8
Other long-term liabilities	45.1	47.5
Deferred income taxes	7.8	8.4
Commitments and contingencies (Note 10)
Partners’ capital (Note 9):
Crestwood Equity Partners LP partners’ capital (69,487,799 and 68,555,305 common and subordinated units issued and outstanding at June 30, 2016 and December 31, 2015)	1,948.1	2,227.6
Preferred units (63,559,359 and 60,718,245 units issued and outstanding at June 30, 2016 and December 31, 2015)	545.5	535.8
Total company partners’ capital	2,493.6	2,763.4
Interest of non-controlling partners in subsidiaries	187.8	183.5
Total partners’ capital	2,681.4	2,946.9
Total liabilities and partners’ capital	4,593.4	5,762.8
Crestwood Midstream Partners LP
Assets
Cash	0.2	0.1
Accounts receivable	244.3	236.5
Inventory	43.5	44.5
Assets from price risk management activities	9.5	32.6
Assets Held-for-sale, Not Part of Disposal Group, Current	55.0	0.0
Prepaid expenses and other current assets	10.3	19.9
Total current assets	362.8	333.6
Property, plant and equipment	2,869.0	4,077.7
Less: accumulated depreciation and depletion	513.1	552.0
Property, plant and equipment, net	2,355.9	3,525.7
Intangible assets	930.3	959.3
Less: accumulated amortization	214.6	197.9
Intangible assets, net	715.7	761.4
Goodwill	249.5	1,085.5
Investment in unconsolidated affiliates (Note 4)	1,099.1	254.3
Other assets	2.9	3.1
Total assets	4,785.9	5,963.6
Current liabilities:
Accounts payable	161.8	141.4
Accrued expenses and other liabilities (Note 3)	94.5	103.3
Liabilities from price risk management activities	10.9	7.4
Current portion of long-term debt (Note 7)	0.9	0.9
Total current liabilities	268.1	253.0
Long-term debt, less current portion (Note 7)	1,581.6	2,501.8
Other long-term liabilities	40.9	43.3
Deferred income taxes	0.7	0.4
Partners’ capital (Note 9):
Total company partners’ capital	2,706.8	2,981.6
Interest of non-controlling partners in subsidiaries	187.8	183.5
Total partners’ capital	2,894.6	3,165.1
Total liabilities and partners’ capital	$ 4,785.9	$ 5,963.6

XML

Consolidated Balance Sheets (Parenthetical) - shares	Jun. 30, 2016	Dec. 31, 2015
Statement of Financial Position [Abstract]
Limited Partners' Capital Account, Units Issued	69,487,799	68,555,305
Limited Partners' Capital Account, Units Outstanding	69,487,799	68,555,305
Preferred Units, Issued	63,559,359	60,718,245
Preferred Units, Outstanding	63,559,359	60,718,245

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Consolidated Statements of Operations - USD ($) shares in Thousands, $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015
Revenues:
Gathering and processing	$ 199.1	$ 263.3	$ 361.6	$ 524.2
Marketing, supply and logistics	257.4	196.5	463.9	473.7
Total product revenue	456.5	459.8	825.5	997.9
Gathering and processing	69.7	82.4	145.4	170.8
Storage and transportation	53.8	68.5	113.2	136.1
Marketing, supply and logistics	21.2	29.7	52.4	66.1
Related party (Note 13)	0.7	1.1	1.4	2.1
Total services revenues	145.4	181.7	312.4	375.1
Total revenues	601.9	641.5	1,137.9	1,373.0
Costs of product/services sold (exclusive of items shown separately below):
Gathering and processing	221.9	285.3	397.3	543.5
Marketing, supply and logistics	210.0	147.1	376.0	389.3
Related party (Note 11)	4.4	7.7	8.7	16.0
Total product costs	436.3	440.1	782.0	948.8
Gathering and processing	0.0	0.1	0.1	0.3
Storage and transportation	1.9	5.3	4.8	10.6
Marketing, supply and logistics	11.8	14.0	26.5	29.5
Total service costs	13.7	19.4	31.4	40.4
Total costs of products/services sold	450.0	459.5	813.4	989.2
Expenses:
Operations and maintenance	45.0	43.9	86.8	94.5
General and administrative	28.9	30.6	51.9	58.1
Depreciation, amortization and accretion	64.4	74.8	126.7	149.0
Total Expenses	138.3	149.3	265.4	301.6
Loss on long-lived assets, net	(32.7)	(0.6)	(32.7)	(1.6)
Goodwill impairment	0.0	(281.0)	(109.7)	(281.0)
Operating loss	(19.1)	(248.9)	(83.3)	(200.4)
Earnings from unconsolidated affiliates, net	6.2	5.0	12.7	8.4
Interest and debt expense, net	(34.3)	(35.4)	(70.4)	(69.0)
Gains (Losses) on Extinguishment of Debt	10.0	(17.1)	10.0	(17.1)
Other income, net	0.1	0.1	0.2	0.3
Loss before income taxes	(37.1)	(296.3)	(130.8)	(277.8)
Provision (benefit) for income taxes	0.0	(0.3)	0.0	0.1
Net loss	(37.1)	(296.0)	(130.8)	(277.9)
Net Income (Loss) Attributable to Noncontrolling Interest	6.0	(256.0)	11.9	(246.2)
Net income (loss) attributable to parent	(43.1)	(40.0)	(142.7)	(31.7)
Net income (loss) attributable to preferred unit holders	8.1	0.0	9.7	0.0
Net loss attributable to partners	(51.2)	(40.0)	(152.4)	(31.7)
Subordinated unitholders' interest in net loss	0.0	(0.9)	0.0	(0.7)
Common unitholders' interest in net loss	$ (51.2)	$ (39.1)	$ (152.4)	$ (31.0)
Net loss per limited partner unit:
Basic (in dollars per share)	$ (0.74)	$ (2.14)	$ (2.21)	$ (1.69)
Diluted (in dollars per share)	$ (0.74)	$ (2.14)	$ (2.21)	$ (1.70)
Weighted-average limited partners’ units outstanding (in thousands):
Basic (units)	69,044	18,284	68,978	18,282
Dilutive units (units)	0	439	0	439
Diluted (units)	69,044	18,723	68,978	18,721
Crestwood Midstream Partners LP
Revenues:
Gathering and processing	$ 199.1	$ 263.3	$ 361.6	$ 524.2
Marketing, supply and logistics	257.4	196.5	463.9	473.7
Total product revenue	456.5	459.8	825.5	997.9
Gathering and processing	69.7	82.4	145.4	170.8
Storage and transportation	53.8	68.5	113.2	136.1
Marketing, supply and logistics	21.2	29.7	52.4	66.1
Related party (Note 13)	0.7	1.1	1.4	2.1
Total services revenues	145.4	181.7	312.4	375.1
Total revenues	601.9	641.5	1,137.9	1,373.0
Costs of product/services sold (exclusive of items shown separately below):
Gathering and processing	221.9	285.3	397.3	543.5
Marketing, supply and logistics	210.0	147.1	376.0	389.3
Related party (Note 11)	4.4	7.7	8.7	16.0
Total product costs	436.3	440.1	782.0	948.8
Gathering and processing	0.0	0.1	0.1	0.3
Storage and transportation	1.9	5.3	4.8	10.6
Marketing, supply and logistics	11.8	14.0	26.5	29.5
Total service costs	13.7	19.4	31.4	40.4
Total costs of products/services sold	450.0	459.5	813.4	989.2
Expenses:
Operations and maintenance	41.4	43.9	83.1	94.5
General and administrative	28.0	27.3	50.2	52.9
Depreciation, amortization and accretion	67.1	69.5	132.0	138.3
Total Expenses	136.5	140.7	265.3	285.7
Loss on long-lived assets, net	(32.7)	(0.7)	(32.7)	(1.5)
Goodwill impairment	0.0	(68.6)	(109.7)	(68.6)
Operating loss	(17.3)	(28.0)	(83.2)	28.0
Earnings from unconsolidated affiliates, net	6.2	5.0	12.7	8.4
Interest and debt expense, net	(34.3)	(32.6)	(70.4)	(62.5)
Gains (Losses) on Extinguishment of Debt	10.0	(17.1)	10.0	(17.1)
Loss before income taxes	(35.4)	(72.7)	(130.9)	(43.2)
Provision (benefit) for income taxes	0.2	0.1	0.0	0.5
Net loss	(35.6)	(72.8)	(130.9)	(43.7)
Net Income (Loss) Attributable to Noncontrolling Interest	6.0	5.7	11.9	11.3
Net income (loss) attributable to parent	(41.6)	(78.5)	(142.8)	(55.0)
Net income (loss) attributable to preferred unit holders	0.0	7.5	0.0	16.7
Net loss attributable to partners	$ (41.6)	$ (86.0)	$ (142.8)	$ (71.7)

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Consolidated Statements of Comprehensive Income - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015
Statement of Comprehensive Income [Abstract]
Net loss	$ (37.1)	$ (296.0)	$ (130.8)	$ (277.9)
Change in fair value of Suburban Propane Partners, L.P. units	0.5	(0.4)	1.3	(0.4)
Comprehensive Income (Loss), Net of Tax, Including Portion Attributable to Noncontrolling Interest	(36.6)	(296.4)	(129.5)	(278.3)
Comprehensive Income (Loss), Net of Tax, Attributable to Noncontrolling Interest	6.0	(256.0)	11.9	(246.2)
Comprehensive loss attributable to Crestwood Equity Partners LP	$ (42.6)	$ (40.4)	$ (141.4)	$ (32.1)

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Consolidated Statement of Partners' Capital - USD ($) $ in Millions	Total	Preferred Units	Common unit	Non-Controlling Partners	Partners' Capital	Crestwood Midstream Partners LP	Crestwood Midstream Partners LP Common unit	Crestwood Midstream Partners LP Non-Controlling Partners	Crestwood Midstream Partners LP Partners' Capital	Common Units	Preferred Units	Subordinated Units
Common Unit, Outstanding										68,200,000		400,000
Preferred Units, Outstanding	60,718,245										60,700,000
Preferred Stock Dividends, Shares	2,841,114										2,800,000
Balance at December 31, 2015 at Dec. 31, 2015	$ 2,763.4	$ 535.8	$ 2,227.6	$ 183.5	$ 2,946.9	$ 2,981.6	$ 2,981.6	$ 183.5	$ 3,165.1
Increase (Decrease) in Partners' Capital [Roll Forward]
Distributions to partners		0.0	(137.0)	(7.6)	(144.6)	148.2	(140.6)	(7.6)	(148.2)
Change in fair value of Suburban Propane Partners, L.P. units	1.3	0.0	1.3	0.0	1.3
Unit-based compensation charges		0.0	9.3	0.0	9.3		9.3	0.0	9.3
Partners' Capital Account, Units, Unit-based Compensation										900,000
Taxes paid for unit-based compensation vesting		0.0	(0.6)	0.0	(0.6)		(0.6)	0.0	(0.6)
Other		0.0	(0.1)	0.0	(0.1)		(0.1)	0.0	(0.1)
Net income (loss) attributable to preferred unit holders	9.7	9.7				0.0
Net loss attributable to partners	(152.4)		(152.4)			(142.8)
Net Income (Loss) Attributable to Noncontrolling Interest	11.9			11.9		11.9
Net loss	(130.8)				(130.8)	(130.9)	(142.8)		(130.9)
Balance at June 30, 2016 at Jun. 30, 2016	$ 2,493.6	$ 545.5	$ 1,948.1	$ 187.8	$ 2,681.4	$ 2,706.8	$ 2,706.8	$ 187.8	$ 2,894.6
Common Unit, Outstanding										69,100,000		400,000
Preferred Units, Outstanding	63,559,359										63,500,000

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Consolidated Statements of Cash Flows - USD ($) $ in Millions	6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015
Operating activities
Net loss	$ (130.8)	$ (277.9)
Adjustments to reconcile net loss to net cash provided by operating activities:
Depreciation, amortization and accretion	126.7	149.0
Amortization of debt-related deferred costs, discounts and premiums	3.4	4.4
Market adjustment on interest rate swaps	0.0	(0.5)
Unit-based compensation charges	9.3	11.7
Loss on long-lived assets, net	32.7	1.6
Gains (Losses) on Extinguishment of Debt	(10.0)	17.1
Goodwill impairment	109.7	281.0
Earnings from unconsolidated affiliates, net, adjusted for cash distributions received	(0.8)	(2.1)
Deferred income taxes	(0.6)	(1.6)
Other	0.1	0.4
Changes in operating assets and liabilities	53.3	28.0
Net cash provided by operating activities	193.0	211.1
Investing activities
Purchases of property, plant and equipment	(76.2)	(83.5)
Investment in unconsolidated affiliates	(5.5)	(28.0)
Proceeds from Equity Method Investment, Dividends or Distributions, Return of Capital	5.5	1.0
Net proceeds from sale of assets	942.0	2.1
Net cash provided by (used in) investing activities	865.8	(108.4)
Financing activities
Proceeds from the issuance of long-term debt	1,078.8	2,154.6
Principal payments on long-term debt	(1,987.7)	(2,030.6)
Payments on capital leases	(0.9)	(1.2)
Payments for debt-related deferred costs	(3.3)	(11.7)
Distributions to partners	137.0	51.5
Distributions paid to non-controlling partners	(7.6)	(152.4)
Taxes paid for unit-based compensation vesting	(0.6)	(3.7)
Other	(0.1)	(0.1)
Net cash used in financing activities	(1,058.4)	(110.2)
Net change in cash	0.4	(7.5)
Cash at beginning of period	0.5
Cash at end of period	0.9	1.3
Supplemental schedule of noncash investing and financing activities
Net change to property, plant and equipment through accounts payable and accrued expenses	(11.9)	(11.3)
Crestwood Midstream Partners LP
Early Repayment of Senior Debt	0.0	(13.6)
Operating activities
Net loss	(130.9)	(43.7)
Adjustments to reconcile net loss to net cash provided by operating activities:
Depreciation, amortization and accretion	132.0	138.3
Amortization of debt-related deferred costs, discounts and premiums	3.4	3.9
Unit-based compensation charges	9.3	10.5
Loss on long-lived assets, net	32.7	1.5
Gains (Losses) on Extinguishment of Debt	(10.0)	17.1
Goodwill impairment	109.7	68.6
Earnings from unconsolidated affiliates, net, adjusted for cash distributions received	(0.8)	(2.1)
Deferred income taxes	0.2	0.3
Other	0.1	0.2
Changes in operating assets and liabilities	50.3	8.9
Net cash provided by operating activities	196.0	203.5
Investing activities
Purchases of property, plant and equipment	(76.2)	(83.5)
Investment in unconsolidated affiliates	(5.5)	(27.8)
Proceeds from Equity Method Investment, Dividends or Distributions, Return of Capital	5.5	1.0
Net proceeds from sale of assets	942.0	2.1
Net cash provided by (used in) investing activities	865.8	(108.2)
Financing activities
Proceeds from the issuance of long-term debt	1,078.8	1,865.1
Principal payments on long-term debt	(1,987.5)	(1,713.2)
Payments on capital leases	(0.9)	(1.2)
Payments for debt-related deferred costs	(3.3)	(11.7)
Distributions to partners	(148.2)	(225.2)
Distributions to partners	148.2	225.2
Distributions paid to non-controlling partners	0.0	0.0
Taxes paid for unit-based compensation vesting	(0.6)	(2.1)
Other	0.0	(0.2)
Net cash used in financing activities	(1,061.7)	(102.1)
Net change in cash	0.1	(6.8)
Cash at beginning of period	0.1	7.6
Cash at end of period	0.2	0.8
Supplemental schedule of noncash investing and financing activities
Net change to property, plant and equipment through accounts payable and accrued expenses	$ (11.9)	$ (11.3)

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Organization and Business Description

6 Months Ended

Jun. 30, 2016

Disclosure Partnership Organization And Basis Of Presentation Narrative [Abstract]

Organization and Business Description

Business Description

The accompanying notes to the consolidated financial statements apply to Crestwood Equity Partners LP and Crestwood Midstream Partners LP, unless otherwise indicated. References in this report to “we,” “us,” “our,” “ours,” “our company,” the “partnership,” the “Company,” "Crestwood Equity," “CEQP,” and similar terms refer to either Crestwood Equity Partners LP itself or Crestwood Equity Partners and its consolidated subsidiaries, as the context requires. Unless otherwise indicated, references to "Crestwood Midstream" and "CMLP" refer to Crestwood Midstream Partners LP and its consolidated subsidiaries.

The accompanying consolidated financial statements and related notes should be read in conjunction with our 2015 Annual Report on Form 10-K filed with the Securities and Exchange Commission (SEC) on February 29, 2016. The financial information as of June 30, 2016, and for the three and six months endedJune 30, 2016 and 2015, is unaudited. The consolidated balance sheets as of December 31, 2015, were derived from the audited balance sheets filed in our 2015 Annual Report on Form 10-K.

Organization

Crestwood Equity is a publicly-traded (NYSE: CEQP) Delaware limited partnership that develops, acquires, owns or controls, and operates primarily fee-based assets and operations within the energy midstream sector. We provide broad-ranging infrastructure solutions across the value chain to service premier liquids-rich natural gas and crude oil shale plays across the United States. We own and operate a diversified portfolio of crude oil and natural gas gathering, processing, storage and transportation assets and connect fundamental energy supply with energy demand across North America. Crestwood Equity is a holding company and all of its consolidated operating assets are owned by or through its wholly-owned subsidiary, Crestwood Midstream, a Delaware limited partnership.

Description of Business

In conjunction with the Simplification Merger (as defined in Note 2), we modified our segments and our financial statements to reflect three operating and reporting segments: (i) gathering and processing operations; (ii) storage and transportation operations; and (iii) marketing, supply and logistics operations (formerly NGL and crude services operations). Consequently, the results of our Arrow operations are now reflected in our gathering and processing operations for all periods presented and our COLT and Powder River Basin Industrial Complex, LLC (PRBIC) operations are now reflected in our storage and transportation operations for all periods presented. These respective operations were previously included in our NGL and crude services operations. For a further description of our operating and reporting segments, see our 2015 Annual Report on Form 10-K.

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Summary of Significant Accounting Policies

6 Months Ended

Jun. 30, 2016

Accounting Policies [Abstract]

Summary of Significant Accounting Policies

Basis of Presentation and Summary of Significant Accounting Policies

Basis of Presentation

Our consolidated financial statements are prepared in accordance with accounting principles generally accepted in the United States of America (GAAP) and include the accounts of all consolidated subsidiaries after the elimination of all intercompany accounts and transactions. In management’s opinion, all necessary adjustments to fairly present our results of operations, financial position and cash flows for the periods presented have been made and all such adjustments are of a normal and recurring nature. Certain information and footnote disclosures normally included in annual consolidated financial statements prepared in accordance with GAAP have been omitted pursuant to the rules and regulations of the SEC.

In May 2015, CEQP, Crestwood Midstream and certain of their affiliates entered into a definitive agreement under which Crestwood Midstream would merge with a wholly-owned subsidiary of CEQP, with Crestwood Midstream surviving as a wholly-owned subsidiary of CEQP (the Simplification Merger). In conjunction with the closing of the Simplification Merger on September 30, 2015, Crestwood Equity contributed 100% of its interest in Crestwood Operations LLC (Crestwood Operations) to Crestwood Midstream. As a result of this equity transaction, Crestwood Midstream controls the operating and financial decisions of Crestwood Operations. Crestwood Midstream accounted for this transaction as a reorganization of entities under common control and the accounting standards related to such transactions requires Crestwood Midstream to retroactively adjust Crestwood Midstream's historical results to reflect the operations of Crestwood Operations as being acquired on June 19, 2013, the date in which Crestwood Midstream and Crestwood Operations came under common control. Prior to the Simplification Merger, Crestwood Equity consolidated the results of Crestwood Operations in its financial statements and as such, this transaction had no impact on its historical financial statements.

Beginning in the third quarter of 2015, we changed our income statement to classify the revenues associated with the products to which we take title as product revenues in our consolidated statement of operations. As such, we reclassified our historical consolidated statements of operations for the three and six months endedJune 30, 2015 to reflect this change. We classify all other revenues as service revenues in our consolidated statement of operations.

Significant Accounting Policies

There were no material changes in our significant accounting policies from those described in our 2015 Annual Report on Form 10-K. Below is an update of certain of our accounting policies.

Principles of Consolidation

We consolidate entities when we have the ability to control or direct the operating and financial decisions of the entity or when we have a significant interest in the entity that give us the ability to direct the activities that are significant to that entity. The determination to consolidate or apply the equity method of accounting to an entity can also require us to evaluate whether the entity is considered a variable interest entity. This evaluation, along with the determination of our ability to control, direct or exert significant influence over an entity involves the use of judgment. We apply the equity method of accounting where we can exert significant influence over, but do not control or direct the policies, decisions or activities of an entity. We use the cost method of accounting where we are unable to exert significant influence over the entity.

In April 2016, our wholly-owned subsidiary, Crestwood Pipeline and Storage Northeast LLC (Crestwood Northeast) and Con Edison Gas Pipeline and Storage Northeast, LLC (CEGP), a wholly-owned subsidiary of Consolidated Edison, Inc. (Con Edison), entered into a definitive agreement to form a joint venture, Stagecoach Gas Services LLC (Stagecoach Gas), to own and further develop our existing natural gas pipeline and storage business located in southern New York and northern Pennsylvania (the NE S&T assets) and our 37.5 mile intrastate natural gas pipeline located in New York which is owned by Crestwood Pipeline East LLC (Pipeline East). On June 3, 2016, we contributed to Stagecoach Gas the entities owning the NE S&T assets, CEGP contributed $945 million to Stagecoach Gas in exchange for a 50% equity interest in Stagecoach Gas, and Stagecoach Gas distributed to Crestwood Northeast the net cash proceeds received from CEGP. Our NE S&T assets were previously included in our storage and transportation segment.

Effective June 3, 2016, we deconsolidated the NE S&T assets as a result of the contribution of these assets to Stagecoach Gas as described above and began accounting for our 50% equity interest in Stagecoach Gas under the equity method of accounting and recorded our Pipeline East assets as assets held for sale as of June 30, 2016. See Notes 3 and 4 for a further discussion of our investment in Stagecoach Gas and our assets held for sale. The deconsolidation of our NE S&T assets resulted in a decrease of $1,094.6 million in property, plant and equipment, net, $8.5 million of intangible assets, net and $10.9 million of other assets and liabilities, net as of June 30, 2016. For a discussion of decreases in goodwill associated with the joint venture transactions, see "Goodwill" below.

Property, Plant and Equipment

Property, plant and equipment is recorded at its original cost of construction or, upon acquisition, at the fair value of the assets acquired. The accounting predecessor of Crestwood Equity acquired the accounting predecessor of Crestwood Midstream in October 2010, and accordingly recorded its acquisition of Crestwood Midstream's property, plant and equipment related to its gathering and processing assets in the Barnett Shale at fair value on that date. The resulting increase to Crestwood Midstream's property, plant and equipment was not pushed down by Crestwood Equity to Crestwood Midstream's balance sheet, as permitted by GAAP.

We evaluate our long-lived assets for impairment whenever events or changes in circumstances indicate that the amount of an asset may not be recoverable. If such events or changes in circumstances are present, a loss is recognized if the carrying value of the asset is in excess of the sum of the undiscounted cash flows expected to result from the use of the asset and its eventual disposition. During 2015, Crestwood Equity recorded a $354.4 million impairment of its property, plant and equipment related to its gathering and processing assets in the Barnett Shale. Crestwood Midstream did not record an impairment of its property, plant and equipment related to its gathering and processing assets in the Barnett Shale as the sum of the undiscounted cash flows expected to result from the use of the assets and their eventual disposition exceeded the carrying value of the property, plant and equipment by over 30%. As a result, Crestwood Midstream's property, plant and equipment exceeds Crestwood Equity's property, plant and equipment related to its gathering and processing assets in the Barnett Shale as of June 30, 2016 and December 31, 2015.

Assets Held for Sale

We classify assets (or groups of assets) to be disposed of as held for sale when specific criteria have been met. Assets classified as held for sale are recorded at the lower of the carrying value or the estimated fair value less cost to sell of those assets . We cease depreciation and amortization of the assets in the period they are considered held for sale.

Goodwill

Our goodwill represents the excess of the amount we paid for a business over the fair value of the net identifiable assets acquired. We evaluate goodwill for impairment annually on December 31, and whenever events indicate that it is more likely than not that the fair value of a reporting unit could be less than its carrying amount. This evaluation requires us to compare the fair value of each of our reporting units to its carrying value (including goodwill). If the fair value exceeds the carrying amount, goodwill of the reporting unit is not considered impaired.

We estimate the fair value of our reporting units based on a number of factors, including discount rates, projected cash flows, and the potential value we would receive if we sold the reporting unit. We also compare the total fair value of our reporting units to our overall enterprise value, which considers the market value for our common and preferred units. Estimating projected cash flows requires us to make certain assumptions as it relates to the future operating performance of each of our reporting units (which includes assumptions, among others, about estimating future operating margins and related future growth in those margins, contracting efforts and the cost and timing of facility expansions) and assumptions related to our customers, such as their future capital and operating plans and their financial condition. When considering operating performance, various factors are considered such as current and changing economic conditions and the commodity price environment, among others. Due to the imprecise nature of these projections and assumptions, actual results can and often do, differ from our estimates. If the assumptions embodied in the projections prove inaccurate, we could incur a future impairment charge. In addition, the use of the income approach to determine the fair value of our reporting units (see further discussion of the use of the income approach below) could result in a different fair value if we had utilized a market approach, or a combination thereof.

We acquired substantially all of our reporting units in 2013, 2012 and 2011, which required us to record the assets, liabilities and goodwill of each of those reporting units at fair value on the date they were acquired. As a result, any level of decrease in the forecasted cash flows of these businesses or increases in the discount rates utilized to value those businesses from their respective acquisition dates would likely result in the fair value of the reporting unit falling below the carrying value of the reporting unit, and could result in an assessment of whether that reporting unit's goodwill is impaired.

Commodity prices have continued to decline since 2014, and that decline has adversely impacted forecasted cash flows, discount rates and stock/unit prices for most companies in the midstream industry, including us. In particular, due to the significant, sustained decrease in the market price of our common units during the first quarter of 2016, we evaluated the carrying value of our reporting units and determined it was more likely than not that the goodwill associated with several of our reporting units was impaired as of March 31, 2016. As a result of further analysis of the fair value of our reporting units, we recorded goodwill impairments on several of our reporting units during the first quarter of 2016. We did not record any goodwill impairments during the three months endedJune 30, 2016.

The following table summarizes the goodwill of our various reporting units (in millions):

	Goodwill at		Goodwill Impairments during the  Six Months Ended		Deconsolidation of NE S&T Assets at		Goodwill at
	December 31, 2015		June 30, 2016		June 30, 2016		June 30, 2016
Gathering and Processing
Marcellus	$	8.6	$	8.6	$	—	$	—
Arrow	45.9		—		—		45.9
Storage and Transportation
Northeast Storage and Transportation	726.3		—		726.3		—
COLT	44.9		13.7		—		31.2
Marketing, Supply and Logistics					—
Supply and Logistics	167.2		65.5		—		101.7
Storage and Terminals	50.5		14.1		—		36.4
US Salt	12.6		—		—		12.6
Trucking	29.5		7.8		—		21.7
Total	$	1,085.5	$	109.7	$	726.3	$	249.5

The goodwill impairments recorded during the first quarter of 2016 primarily resulted from increasing the discount rates utilized in determining the fair value of the reporting units for certain of those reporting units considering the significant, sustained decrease in the market price of our common units and the continued decrease in commodity prices and its impact on the midstream industry and our customers. Our COLT, Supply and Logistics, Storage and Terminals and Trucking reporting units also experienced impairments during 2015 based on the impact that the prolonged low commodity price environment is expected to have on the demand for future services provided by these operations. Despite increases in the operating results of these reporting units from 2013 to 2015, in light of our modified expectations, we revised our cash flow forecasts for these operations at December 31, 2015 in light of our current view that these operations will not grow as fast or as significantly in the future as originally forecasted in 2013 when the assets were acquired.

The remaining goodwill related to these reporting units represented the fair value of the goodwill, which is a Level 3 fair value measurement. We utilized the income approach to determine the fair value of our reporting units given the limited availability of comparable market-based transactions as of March 31, 2016 and December 31, 2015, and we utilized discount rates ranging from 10% to 19% in applying the income approach to determine the fair value of our reporting units with goodwill as of March 31, 2016.

During the three months endedJune 30, 2015, Crestwood Midstream recorded goodwill impairments of $8.3 million, $28.4 million and $31.9 million related to its Fayetteville, West Coast and Watkins Glen reporting units, respectively. The impairment of the Fayetteville and West Coast goodwill primarily resulted from increasing the discount rate utilized in determining the fair value of the reporting units from 9% to 10%, considering the decrease in commodity prices and its impact on the midstream industry and Crestwood Midstream's customers in those areas. The impairment of the Watkins Glen goodwill primarily resulted from increasing the discount rate utilized in determining the fair value of the reporting unit from 10.5% to 13.3% and delays and uncertainties in the permitting of the proposed storage facility.

In addition to the above goodwill impairments recorded during the three months endedJune 30, 2015, Crestwood Equity recorded a goodwill impairment of its Barnett reporting unit of approximately $212.4 million. The impairment primarily resulted from increasing the discount rate utilized in determining the fair value of the reporting unit from 9% to 11%, considering the recent actions of its primary customer in the Barnett Shale, Quicksilver, related to its filing for protection under Chapter 11 of the U.S. Bankruptcy Code in March 2015.

Deferred Financing Costs

Deferred financing costs represent costs associated with obtaining long-term financing and are amortized over the term of the related debt using a method which approximates the effective interest method and has a weighted average life of six years. Effective January 1, 2016, we adopted the provisions of Accounting Standards Update (ASU) 2015-03, Interest - Imputation of Interest (Subtopic 835-30), which requires us to classify our net deferred financing costs of $37.6 million and $40.9 million as a reduction of long-term debt on our consolidated balance sheets at June 30, 2016 and December 31, 2015. Such costs were previously reflected as intangible assets on our consolidated balance sheets.

New Accounting Pronouncements Issued But Not Yet Adopted

As of June 30, 2016, the following accounting standards had not yet been adopted by us:

In May 2014, the Financial Accounting Standards Board (FASB) issued ASU 2014-09, Revenue from Contracts with Customers, which outlines a single comprehensive model for entities to use in accounting for revenue arising from contracts with customers and supersedes current revenue recognition guidance. We expect to adopt the provisions of this standard effective January 1, 2018 and are currently evaluating the method by which we will adopt the standard and the impact that this standard will have on our consolidated financial statements.

In February 2016, the FASB issued ASU 2016-02, Leases (Topic 842), which revises the accounting for leases by requiring certain leases to be recognized as assets and liabilities on the balance sheet, and requiring companies to disclose additional information about their leasing arrangements. We expect to adopt the provisions of this standard effective January 1, 2019 and are currently evaluating the impact that this standard will have on our consolidated financial statements.

In March 2016, the FASB issued ASU 2016-09, Compensation - Stock Compensation (Topic 718):Improvements to Employee Share-Based Payment Accounting, which is intended to improve the accounting for employee share-based payments. The ASU simplifies several aspects of the accounting for share-based payment award transactions, including the classification of awards as either equity or liabilities and presentation on the statement of cash flows. We expect to adopt the provisions of this standard effective January 1, 2017 and are currently evaluating the impact that this standard may have on our consolidated financial statements.

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Certain Balance Sheet Information

6 Months Ended

Jun. 30, 2016

Balance Sheet Related Disclosures [Abstract]

Certain Balance Sheet Information

Certain Balance Sheet Information

Assets Held for Sale

In conjunction with the contribution agreement related to Stagecoach Gas, we agreed to contribute our wholly-owned subsidiary, Pipeline East, to Stagecoach Gas, CEGP has agreed to contribute approximately $30 million to Stagecoach Gas, and Stagecoach Gas will distribute to us the net cash proceeds received from CEGP. We classified the property, plant and equipment and goodwill to be contributed to Stagecoach Gas as assets held for sale on our consolidated balance sheet at their fair value at June 30, 2016. The fair value is based on the consideration to be received from the contribution of Pipeline East to Stagecoach Gas and the forecasted discounted cash flows to be received from our investment in Stagecoach Gas, which is a Level 3 fair value measurement. The sale is contingent upon New York State regulatory approval and satisfaction of certain other closing conditions, which we believe is probable at June 30, 2016.

Accrued Expenses and Other Liabilities

Accrued expenses and other liabilities consisted of the following at June 30, 2016 and December 31, 2015 (in millions):

	CEQP				CMLP
	June 30,		December 31,		June 30,		December 31,
	2016		2015		2016		2015
Accrued expenses	$	35.5	$	46.4	$	33.8	$	44.1
Accrued property taxes	12.3		4.8		7.3		4.8
Accrued product purchases payable	2.8		1.5		2.8		1.5
Tax payable	0.6		0.5		0.6		0.5
Interest payable	23.2		26.2		23.2		26.2
Accrued additions to property, plant and equipment	2.9		10.4		2.9		10.4
Capital leases	1.3		1.6		1.3		1.6
Deferred revenue	22.6		14.2		22.6		14.2
Total accrued expenses and other liabilities	$	101.2	$	105.6	$	94.5	$	103.3

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Investments in Unconsolidated Affiliates

6 Months Ended

Jun. 30, 2016

Equity Method Investments and Joint Ventures [Abstract]

Investments in Unconsolidated Affiliates

Investments in Unconsolidated Affiliates

Stagecoach Gas Services LLC. In April 2016, Crestwood Northeast and CEGP entered into a definitive agreement to form the Stagecoach JV to own and further develop our NE S&T assets. Pursuant to the contribution agreement, we contributed to Stagecoach Gas the entities owning the NE S&T assets, CEGP contributed $945 million to Stagecoach Gas in exchange for a 50% equity interest in Stagecoach Gas, and Stagecoach Gas distributed to Crestwood Northeast the cash proceeds received (net of approximately $3 million of cash transferred to the joint venture) from CEGP. Effective June 3, 2016, we deconsolidated the NE S&T assets as a result of this transaction and began accounting for our 50% equity interest in Stagecoach Gas under the equity method of accounting, and we reflected our investment at $844 million, which represented the fair value of our proportionate share of the assets at June 3, 2016 and is based on the forecasted discounted cash flows of the investment (which is a Level 3 fair value measurement). We recognized a loss on the deconsolidation of the NE S&T assets of approximately $32.9 million. See our 2015 Annual Report on Form 10-K for a description of our NE S&T assets.

Net Investments and Earnings

Our net investments in and earnings from our unconsolidated affiliates are as follows (in millions, unless otherwise stated):

	Ownership Percentage			Investment				Earnings (Loss) from Unconsolidated Affiliates
	June 30,			June 30,		December 31,		Three Months Ended June 30,					Six Months Ended June 30,
	2016			2016		2015		2016			2015		2016			2015
Stagecoach Gas Services LLC(1)	50.00	%		$	846.3	$	—	$	2.3		$	—	$	2.3		$	—
Jackalope Gas Gathering Services, L.L.C.(2)	50.00	%	(3)	201.3		202.4		5.9			1.1		11.0			3.6
Tres Palacios Holdings LLC(4)	50.01	%		36.7		36.8		(2.3		)	0.6		(1.5		)	1.5
Powder River Basin Industrial Complex, LLC(5)	50.01	%		14.8		15.1		0.3			3.3		0.9			3.3
Total				$	1,099.1	$	254.3	$	6.2		$	5.0	$	12.7		$	8.4

(1) As of June 30, 2016, our equity in the underlying net assets of Stagecoach Gas exceeded our investment balance by approximately $50.8 million. Our Stagecoach Gas investment is included in our storage and transportation segment.

(2) As of June 30, 2016, our equity in the underlying net assets of Jackalope Gas Gathering Services, L.L.C. (Jackalope) exceeded our investment balance by approximately $0.8 million. We amortize this amount over 20 years, which represents the life of Jackalope’s gathering agreement with Chesapeake Energy Corporation (Chesapeake), and we reflect the amortization as an increase in our earnings from unconsolidated affiliates. We recorded amortization of less than $0.1 million for both the three and six months endedJune 30, 2016 and $0.7 million and $1.5 million for the three and six months endedJune 30, 2015. Our Jackalope investment is included in our gathering and processing segment.

(3) Excludes non-controlling interests related to our investment in Jackalope. See Note 9 for a further discussion of our non-controlling interest related to our investment in Jackalope.

(4) As of June 30, 2016, our equity in the underlying net assets of Tres Palacios Holdings LLC (Tres Holdings) exceeded our investment balance by approximately $28.5 million. We amortize this amount over the life of the Tres Palacios Gas Storage LLC (Tres Palacios) sublease agreement, and we reflect the amortization as an increase in our earnings from unconsolidated affiliates. We recorded amortization of $0.3 million for the three months endedJune 30, 2016 and 2015, and $0.6 million for the six months endedJune 30, 2016 and 2015. Our Tres Holdings investment is included in our storage and transportation segment.

(5) As of June 30, 2016, our equity in the underlying net assets of PRBIC exceeded our investment balance by approximately $22.6 million. We amortize a portion of this amount over the life of PRBIC's property, plant and equipment and its agreement with Chesapeake, and we reflect the amortization as an increase in our earnings from unconsolidated affiliates. Approximately $10.6 million of this excess amount relates to goodwill and, as such, is not subject to amortization. We recorded amortization of approximately $0.4 million and $0.8 million for the three and six months endedJune 30, 2016. During the three and six months ended June 30, 2015, we recorded additional equity earnings of approximately $3.2 million related to a gain associated with the adjustment of our member's capital account by our equity investee. Our PRBIC investment is included in our storage and transportation segment.

Distributions and Contributions

Stagecoach Gas. Stagecoach Gas is required, within 30 days following the end of each quarter, to distribute 65% and 35% of its available cash (as defined in its limited liability company agreement) to CEQP and us, respectively. Because our ownership and distribution percentages differ, we determine the equity earnings from Stagecoach Gas using the Hypothetical Liquidation at Book Value (HLBV) method. Under the HLBV method, a calculation is prepared at each balance sheet date to determine the amount that we would receive if Stagecoach Gas were to liquidate all of its assets, as valued in accordance with GAAP, and distribute that cash to the members. The difference between the calculated liquidation distribution amounts at the beginning and the end of the reporting period, after adjusting for capital contributions and distributions, is our share of the earnings or losses from the equity investment for the period, which approximates how earnings are allocated under the terms of the limited liability company agreement. In July 2016, we received a cash distribution of approximately $3.7 million from Stagecoach Gas.

Jackalope.Jackalope is required, within 30 days following the end of each quarter, to make quarterly distributions of its available cash to its members based on their respective ownership percentage. During the six months endedJune 30, 2016 and 2015, we received cash distributions of approximately $12.1 million and $4.5 million from Jackalope. During the six months endedJune 30, 2015, we contributed approximately $17.9 million to Jackalope.

Tres Holdings. Tres Holdings is required, within 30 days following the end of each quarter, to make quarterly distributions of its available cash (as defined in its limited liability company agreement) to its members based on their respective ownership percentage. During the six months endedJune 30, 2016 and 2015, we received cash distributions of approximately $4.1 million and $2.1 million from Tres Holdings. In July 2016, we received a cash distribution of approximately $2.1 million from Tres Holdings. During the six months endedJune 30, 2016 and 2015, we contributed approximately $5.5 million and $5.7 million to Tres Holdings.

PRBIC. PRBIC is required to make quarterly distributions of its available cash to its members based on their respective ownership percentage. During the six months endedJune 30, 2016 and 2015, we received cash distributions of approximately $1.2 million and $0.7 million from PRBIC. In July 2016, we received a cash distribution of approximately $0.4 million from PRBIC. During the six months endedJune 30, 2015, we contributed approximately $4.2 million to PRBIC.

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Risk Management

6 Months Ended

Jun. 30, 2016

Risk Management - Notional Amounts and Terms of Companys Derivative Financial Instruments [Abstract]

Risk Management

Risk Management

We are exposed to certain market risks related to our ongoing business operations. These risks include exposure to changing commodity prices. We utilize derivative instruments to manage our exposure to fluctuations in commodity prices, which is discussed below. Additional information related to our derivatives is discussed in Note 6.

Commodity Derivative Instruments and Price Risk Management

Risk Management Activities

We sell NGLs to energy related businesses and may use a variety of financial and other instruments including forward contracts involving physical delivery of NGLs, heating oil and crude oil. We periodically enter into offsetting positions to economically hedge against the exposure our customer contracts create. Certain of these contracts and positions are derivative instruments. We do not designate any of our commodity-based derivatives as hedging instruments for accounting purposes. Our commodity-based derivatives are reflected at fair value in the consolidated balance sheets, and changes in the fair value of these derivatives that impact the consolidated statements of operations are reflected in costs of product/services sold. During the three and six months endedJune 30, 2016, the impact to the statement of operations related to our commodity-based derivatives reflected in costs of product/services sold was a gain of $1.3 million and $2.0 million. During the three and six months endedJune 30, 2015, the impact to the statement of operations related to our commodity-based derivatives reflected in costs of product/services sold was a gain of $2.9 million and $5.3 million. We attempt to balance our contractual portfolio in terms of notional amounts and timing of performance and delivery obligations. This balance in the contractual portfolio significantly reduces the volatility in costs of product/services sold related to these instruments.

Commodity Price and Credit Risk

Notional Amounts and Terms

The notional amounts and terms of our derivative financial instruments include the following at June 30, 2016 and December 31, 2015 (in millions):

	June 30, 2016		December 31, 2015
	Fixed Price Payor	Fixed Price Receiver	Fixed Price Payor	Fixed Price Receiver
Propane, crude and heating oil (barrels)	12.4	13.8	9.1	10.9

Notional amounts reflect the volume of transactions, but do not represent the amounts exchanged by the parties to the financial instruments. Accordingly, notional amounts do not reflect our monetary exposure to market or credit risks.

All contracts subject to price risk had a maturity of 34 months or less; however, 82% of the contracted volumes will be delivered or settled within 12 months.

Credit Risk

Inherent in our contractual portfolio are certain credit risks. Credit risk is the risk of loss from nonperformance by suppliers, customers or financial counterparties to a contract. We take an active role in managing credit risk and have established control procedures, which are reviewed on an ongoing basis. We attempt to minimize credit risk exposure through credit policies and periodic monitoring procedures as well as through customer deposits, letters of credit and entering into netting agreements that allow for offsetting counterparty receivable and payable balances for certain financial transactions, as deemed appropriate. The counterparties associated with our assets from price risk management activities as of June 30, 2016 and December 31, 2015 were energy marketers and propane retailers, resellers and dealers.

Certain of our derivative instruments have credit limits that require us to post collateral. The amount of collateral required to be posted is a function of the net liability position of the derivative as well as our established credit limit with the respective counterparty. If our credit rating were to change, the counterparties could require us to post additional collateral. The amount of additional collateral that would be required to be posted would vary depending on the extent of change in our credit rating as well as the requirements of the individual counterparty. The aggregate fair value of all commodity derivative instruments with credit-risk-related contingent features that were in a liability position at June 30, 2016 and December 31, 2015 was $5.5 million and $3.3 million. At June 30, 2016 and December 31, 2015, we posted less than $0.1 million of collateral for our commodity derivative instruments with credit-risk-related contingent features. In addition, at June 30, 2016 and December 31, 2015, we had a New York Mercantile Exchange (NYMEX) related net derivative liability position of $9.3 million and $20.8 million, for which we posted $6.1 million and $26.7 million of cash collateral in the normal course of business. At June 30, 2016 and December 31, 2015, we also received collateral of $5.0 million and $16.8 million in the normal course of business. All collateral amounts have been netted against the asset or liability with the respective counterparty and are reflected in our consolidated balance sheets as assets and liabilities from price risk management activities.

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Fair Value Measurements

6 Months Ended

Jun. 30, 2016

Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]

Fair Value Measurements

Fair Value Measurements

The accounting standards for fair value measurement establish a three-tier fair value hierarchy, which prioritizes the inputs used in measuring fair value. The hierarchy gives the highest priority to unadjusted quoted prices in active markets for identical assets or liabilities (Level 1 measurement) and the lowest priority to unobservable inputs (Level 3 measurement). The three levels of the fair value hierarchy are as follows:

• Level 1—Quoted prices are available in active markets for identical assets or liabilities as of the reporting date. Active markets are those in which transactions for the asset or liability occur in sufficient frequency and volume to provide pricing information on an ongoing basis. Level 1 primarily consists of financial instruments such as exchange-traded derivatives, listed equities and US government treasury securities.

• Level 2—Pricing inputs are other than quoted prices in active markets included in Level 1, which are either directly or indirectly observable as of the reporting date. Level 2 includes those financial instruments that are valued using models or other valuation methodologies. These models are primarily industry-standard models that consider various assumptions, including quoted forward prices for commodities, time value, volatility factors, and current market and contractual prices for the underlying instruments, as well as other relevant economic measures. Substantially all of these assumptions are observable in the marketplace throughout the full term of the instrument, can be derived from observable data or are supported by observable levels at which transactions are executed in the marketplace. Instruments in this category include non-exchange-traded derivatives such as over the counter (OTC) forwards, options and physical exchanges.

• Level 3—Pricing inputs include significant inputs that are generally less observable from objective sources. These inputs may be used with internally developed methodologies that result in management’s best estimate of fair value.

Cash and Cash Equivalents, Accounts Receivable and Accounts Payable

As of June 30, 2016 and December 31, 2015, the carrying amounts of cash, accounts receivable and accounts payable represent fair value based on the short-term nature of these instruments.

Credit Facility

The fair value of the amount outstanding under our CMLP credit facility approximates its carrying amount as of June 30, 2016 and December 31, 2015, due primarily to the variable nature of the interest rate of the instrument, which is considered a Level 2 fair value measurement.

Senior Notes

We estimate the fair value of our senior notes primarily based on quoted market prices for the same or similar issuances (representing a Level 2 fair value measurement). The following table reflects the carrying value and fair value of our CMLP senior notes (in millions):

	June 30, 2016				December 31, 2015
	Carrying  Amount		Fair Value		Carrying  Amount		Fair Value
Crestwood Midstream 2020 Senior Notes	$	340.8	$	319.9	$	503.3	$	382.3
Crestwood Midstream 2022 Senior Notes	$	436.4	$	400.8	$	600.0	$	437.4
Crestwood Midstream 2023 Senior Notes	$	700.0	$	645.8	$	700.0	$	491.8

Financial Assets and Liabilities

As of June 30, 2016 and December 31, 2015, we held certain assets and liabilities that are required to be measured at fair value on a recurring basis, which include our derivative instruments related to heating oil, crude oil, and NGLs. Our derivative instruments consist of forwards, swaps, futures, physical exchanges and options.

Certain of our derivative instruments are traded on the NYMEX. These instruments have been categorized as Level 1.

Our derivative instruments also include OTC contracts, which are not traded on a public exchange. The fair values of these derivative instruments are determined based on inputs that are readily available in public markets or can be derived from information available in publicly quoted markets. These instruments have been categorized as Level 2.

Our OTC options are valued based on the Black Scholes option pricing model that considers time value and volatility of the underlying commodity. The inputs utilized in the model are based on publicly available information as well as broker quotes. These options have been categorized as Level 2.

Our financial assets and liabilities are classified in their entirety based on the lowest level of input that is significant to the fair value measurement. The assessment of the significance of a particular input to the fair value measurement requires judgment, and may affect the valuation of fair value assets and liabilities and their placement within the fair value hierarchy levels.

The following tables set forth by level within the fair value hierarchy, our financial instruments that were accounted for at fair value on a recurring basis at June 30, 2016 and December 31, 2015 (in millions):

	June 30, 2016
	Fair Value of Derivatives
	Level 1		Level 2		Level 3		Gross Fair Value		Contract Netting(1)			Collateral/Margin Received or Paid			Recorded in Balance Sheet
Assets
Assets from price risk management	$	0.2	$	44.0	$	—	$	44.2	$	(28.9	)	$	(5.8	)	$	9.5
Suburban Propane Partners, L.P. units(2)	4.7		—		—		4.7		—			—			4.7
Total assets at fair value	$	4.9	$	44.0	$	—	$	48.9	$	(28.9	)	$	(5.8	)	$	14.2
Liabilities
Liabilities from price risk management	$	0.2	$	37.5	$	—	$	37.7	$	(28.9	)	$	2.1		$	10.9
Total liabilities at fair value	$	0.2	$	37.5	$	—	$	37.7	$	(28.9	)	$	2.1		$	10.9
	December 31, 2015
	Fair Value of Derivatives
	Level 1		Level 2		Level 3		Gross Fair Value		Contract Netting(1)			Collateral/Margin Received or Paid			Recorded in Balance Sheet
Assets
Assets from price risk management	$	0.5	$	57.8	$	—	$	58.3	$	(13.7	)	$	(12.0	)	$	32.6
Suburban Propane Partners, L.P. units(2)	3.4		—		—		3.4		—			—			3.4
Total assets at fair value	$	3.9	$	57.8	$	—	$	61.7	$	(13.7	)	$	(12.0	)	$	36.0
Liabilities
Liabilities from price risk management	$	0.2	$	41.3	$	—	$	41.5	$	(13.7	)	$	(20.4	)	$	7.4
Total liabilities at fair value	$	0.2	$	41.3	$	—	$	41.5	$	(13.7	)	$	(20.4	)	$	7.4

(1) Amounts represent the impact of legally enforceable master netting agreements that allow us to settle positive and negative positions as well as cash collateral held or placed with the same counterparties.

(2) Amount is reflected in other assets on CEQP's consolidated balance sheets.

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Long-Term Debt

6 Months Ended

Jun. 30, 2016

Text Block [Abstract]

Long-Term Debt

Long-Term Debt

Long-term debt consisted of the following at June 30, 2016 and December 31, 2015 (in millions):

	June 30, 2016		December 31, 2015
Credit Facility	$	139.0	$	735.0
2020 Senior Notes	338.8		500.0
Fair value adjustment of 2020 Senior Notes	2.0		3.3
2022 Senior Notes	436.4		600.0
2023 Senior Notes	700.0		700.0
Other	3.9		5.3
Less: deferred financing costs, net	37.6		40.9
Total Crestwood Midstream debt	1,582.5		2,502.7
Other	—		0.2
Total Crestwood Equity debt	1,582.5		2,502.9
Less: current portion	0.9		1.1
Total long-term debt, less current portion	$	1,581.6	$	2,501.8

Crestwood Midstream Credit Facility

In conjunction with the contribution agreement with CEGP, Crestwood Midstream amended its credit facility during the second quarter of 2016 to, among other things, (i) facilitate the closing of the joint venture and make investments in the joint venture thereafter, and (ii) implement our liability management plan with the net cash proceeds received from Stagecoach Gas, including the repurchase of Crestwood Midstream's senior notes with the borrowings under its credit facility.

At June 30, 2016, Crestwood Midstream had $613.9 million of available capacity under its credit facility considering the most restrictive debt covenants in its credit agreement. At June 30, 2016 and December 31, 2015, Crestwood Midstream's outstanding standby letters of credit were $62.1 million and $62.2 million. Borrowings under the CMLP credit facility accrue interest at prime or Eurodollar based rates plus applicable spreads, which resulted in interest rates between 3.21% and 5.25% at June 30, 2016 and 2.70% and 5.00% at December 31, 2015. The weighted-average interest rate as of June 30, 2016 and December 31, 2015 was 3.30% and 2.70%.

Crestwood Midstream is required under its credit agreement to maintain a net debt to consolidated EBITDA ratio (as defined in its credit agreement) of not more than 5.50 to 1.0, a consolidated EBITDA to consolidated interest expense ratio (as defined in its credit agreement) of not less than 2.50 to 1.0, and a senior secured leverage ratio (as defined in its credit agreement) of not more than 3.75 to 1.0. At June 30, 2016, the net debt to consolidated EBITDA was approximately 3.99 to 1.0, the consolidated EBITDA to consolidated interest expense was approximately 3.82 to 1.0, and the senior secured leverage ratio was 0.34 to 1.0.

Crestwood Midstream Senior Notes

In June 2016, Crestwood Midstream paid approximately $312.9 million to purchase and cancel approximately $161.2 million and $163.6 million of the principal amounts outstanding under its 2020 Senior Notes and 2022 Senior Notes, respectively, utilizing a portion of the proceeds received from Stagecoach Gas, as further discussed in Note 2.  Crestwood Midstream recognized a gain on extinguishment of debt of approximately $10.0 million in conjunction with the early tender of these notes. Crestwood Midstream also paid $4.5 million and $2.6 million of accrued interest on the 2020 Senior Notes and 2022 Senior Notes, respectively, on the date they were tendered.

In March 2016, Crestwood Midstream filed a registration statement with the SEC under which it plans to offer to exchange $700.0 million of its 6.25% 2023 Senior Notes for any and all outstanding notes. The exchange offer was declared effective by the SEC on June 15, 2016 and closed on July 13, 2016. The terms of the exchange notes are substantially identical to the terms of the 2023 Senior Notes, except that the exchange notes are freely tradable. Crestwood Midstream issued the 2023 Senior Notes in March 2015. The net proceeds from the original offering of approximately $688.3 million were used to pay down borrowings under Crestwood Midstream's credit facility and for general partnership purposes.

At June 30, 2016, Crestwood Midstream was in compliance with all of its debt covenants applicable to the CMLP credit facility and its senior notes.

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Earnings Per Limited Partner Unit

6 Months Ended

Jun. 30, 2016

Earnings Per Share [Abstract]

Earnings Per Limited Partner Unit

Earnings Per Limited Partner Unit

Our net income (loss) attributable to Crestwood Equity Partners is allocated to the subordinated and limited partner unitholders based on their ownership percentage after giving effect to net income attributable to the Class A preferred units. We calculate basic net income per limited partner unit using the two-class method. Diluted net income per limited partner unit is computed using the treasury stock method, which considers the impact to net income attributable to Crestwood Equity Partners and limited partner units from the potential issuance of limited partner units.

We exclude potentially dilutive securities from the determination of diluted earnings per unit (as well as their related income statement impacts) when their impact on net income attributable to Crestwood Equity Partners per limited partner unit is anti-dilutive. During the three and six months endedJune 30, 2016, we excluded a weighted-average of 6,355,936 and 6,284,885 common units (representing preferred units), a weighted-average of 438,789 common units in both periods (representing subordinated units), and a weighted-average of 8,438,849 common units in both periods (representing Crestwood Niobrara's preferred units). See Note 9 for additional information regarding the potential conversion of our preferred units and Crestwood Niobrara's preferred units to common units. There were no units excluded from our dilutive earnings per unit as we did not have any anti-dilutive units for the three and six months endedJune 30, 2015 .

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Partners' Capital

6 Months Ended

Jun. 30, 2016

Statement of Partners' Capital [Abstract]

Partners' Capital

Partners’ Capital

Distributions

Crestwood Equity

Limited Partners. A summary of CEQP's limited partner quarterly cash distributions for the six months endedJune 30, 2016 and 2015 is presented below:

Record Date	Payment Date	Per Unit Rate		Cash Distributions (in millions)
2016
February 5, 2016	February 12, 2016	$	1.375	$	95.6
May 6, 2016	May 13, 2016	0.60		41.4
				$	137.0
2015
February 6, 2015	February 13, 2015	$	1.375	$	25.8
May 8, 2015	May 15, 2015	1.375		25.7
				$	51.5

On July 21, 2016,we declared a distribution of $0.60 per limited partner unit to be paid on August 12, 2016, to unitholders of record on August 5, 2016 with respect to the second quarter of 2016.

Preferred Unit Holders. In conjunction with the closing of the Simplification Merger, the CMLP Class A Preferred Units were exchanged for new preferred units of the Company (the Preferred Units) with substantially similar terms and conditions to those of the CMLP Preferred Units. We are required to make quarterly distributions to our preferred unitholders. During the six months endedJune 30, 2016, we issued 2,841,114 Preferred Units to our preferred unitholders in lieu of paying cash distributions of $25.9 million. On July 21, 2016, the board of directors of our general partner authorized the issuance of 1,470,029 Preferred Units to our preferred unit holders for the quarter ended June 30, 2016 in lieu of paying a cash distribution of $13.4 million.

On June 9, 2016, Crestwood Equity filed a shelf registration statement with the SEC under which holders of the Preferred Units may sell the common units into which the Preferred Units are convertible. The registration statement became effective on June 15, 2016. Crestwood Equity registered 7,290,552 common units under the registration statement.

Crestwood Midstream

Prior to the Simplification Merger, the Company indirectly owned a non-economic general partnership interest in Crestwood Midstream and 100% of its incentive distribution rights (IDRs). Crestwood Midstream was also a publicly-traded limited partnership with common units listed on the NYSE. However, as a result of Crestwood Midstream's completion of the Simplification Merger on September 30, 2015, its common units ceased to be listed on the NYSE, the IDRs were eliminated and Crestwood Midstream became a wholly-owned subsidiary of the Company.

During the six months endedJune 30, 2016 and 2015, Crestwood Midstream paid cash distributions of $140.6 million and $51.9 million to Crestwood Equity. During the six months endedJune 30, 2015, Crestwood Midstream paid a cash distribution to its general partner (representing IDRs and distributions related to common units held by the general partner) of approximately $20.9 million.

Limited Partners. The following table presents quarterly cash distributions paid to Crestwood Midstream's limited partners (excluding distributions paid to its general partner on its common units held) during the six months endedJune 30, 2015.

Record Date	Payment Date	Per Unit Rate		Cash Distributions (in millions)
February 6, 2015	February 13, 2015	$	0.41	$	74.3
May 8, 2015	May 15, 2015	0.41		74.3
				$	148.6

Non-Controlling Partners

Crestwood Midstream Class A Preferred Units

As discussed above, in conjunction with the closing of the Simplification Merger, the CMLP Class A Preferred Units were exchanged for new preferred units of Crestwood Equity. Prior to the Simplification Merger, Crestwood Equity classified the CMLP Class A Preferred Units as a component of Interest of Non-Controlling Partners on its consolidated balance sheet.

Crestwood Niobrara Preferred Interest

Crestwood Niobrara issued a preferred interest to a subsidiary of General Electric Capital Corporation and GE Structured Finance, Inc. (collectively, GE) in conjunction with the acquisition of its investment in Jackalope, which is reflected as non-controlling interest in our consolidated financial statements.

Net Income (Loss) Attributable to Non-Controlling Partners

The components of net income (loss) attributable to non-controlling partners for the three and six months endedJune 30, 2016 and 2015, are as follows (in millions):

	Three Months Ended					Six Months Ended
	June 30,					June 30,
	2016		2015			2016		2015
Crestwood Niobrara preferred interests	$	6.0	$	5.7		$	11.9	$	11.3
CMLP net income attributable to non-controlling partners	6.0		5.7			11.9		11.3
Crestwood Midstream limited partner interests	—		(269.2		)	—		(274.2		)
Crestwood Midstream Class A preferred units	—		7.5			—		16.7
CEQP net income (loss) attributable to non-controlling partners	$	6.0	$	(256.0	)	$	11.9	$	(246.2	)

Distributions to Non-Controlling Partners

Crestwood Midstream Limited Partners. As discussed above, Crestwood Midstream paid cash distributions to its limited partners (excluding distributions to its general partner and distributions on the limited partner units that were owned by Crestwood Equity) of $148.6 million during the six months endedJune 30, 2015.

Crestwood Midstream Class A Preferred Unit Holders. During the six months endedJune 30, 2015, Crestwood Midstream issued 838,228 Class A Preferred Units to its preferred unit holders in lieu of paying cash distributions of $21.0 million.

Crestwood Niobrara Preferred Unit Holders. During the six months endedJune 30, 2016 and 2015, Crestwood Niobrara paid cash distributions of $7.6 million and $3.8 million to GE. In July 2016, Crestwood Niobrara paid a cash distribution of $3.8 million to GE for the quarter ended June 30, 2016.

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Commitments and Contingencies

6 Months Ended

Jun. 30, 2016

Commitments and Contingencies Disclosure [Abstract]

Commitments and Contingencies

Commitments and Contingencies

Legal Proceedings

Canadian Class Action Lawsuit. Prior to the completion of our acquisition of Arrow Midstream Holdings, LLC (Arrow) on November 8, 2013, a train transporting over 50,000 barrels of crude oil produced in North Dakota derailed in Lac Megantic, Quebec, Canada on July 6, 2013. The derailment resulted in the death of 47 people, injured numerous others, and caused severe damage to property and the environment.  In October 2013, certain individuals suffering harm in the derailment filed a motion to certify a class action lawsuit in the Superior Court for the District of Megantic, Province of Quebec, Canada, on behalf of all persons suffering loss in the derailment (the Class Action Suit).

In March 2014, the plaintiffs filed their fourth amended motion to name Arrow and numerous other energy companies as additional defendants in the class action lawsuit. The plaintiffs alleged, among other things, that Arrow (i) was a producer of the crude oil being transported on the derailed train, (ii) was negligent in failing to properly classify the crude delivered to the trucks that hauled the crude to the rail loading terminal, and (iii) owed a duty to the petitioners to ensure the safe transportation of the crude being transported.  The motion to authorize the class action and motions in opposition were heard by the Court in June 2014. In June 2015, the Superior Court determined that the Class Action Suit proceeding should be allowed to proceed against certain respondents that have not contributed to the global settlement described below. Because Arrow is a contributing party to the global settlement, the Class Action Suit against Arrow was stayed pending finalization of the global settlement plan in the United States and Canadian bankruptcy proceedings described below.

One of the defendants in the lawsuit, Montreal Main & Atlantic Railway (MM&A), filed bankruptcy actions in the U.S. Bankruptcy Court for the District of Maine and in the Canadian Bankruptcy Court. The bankruptcy trustees in the proceedings approached the respondents in the Class Action Suit (including Arrow) to contribute monetary damages to a global settlement for all claims, including any potential environmental damages, related to the Lac Megantic derailment. Crestwood Midstream agreed to contribute to the global settlement in exchange for a release from all claims related to the derailment, including the Class Action Suit. The Canadian and United States bankruptcy courts approved the bankruptcy plan (including the global settlement which was funded in December 2015). Crestwood Midstream's contribution to the global settlement, in addition to associated legal fees, is fully covered by insurance, and since the global settlement is finalized, Arrow should not be exposed to additional damages relating to the derailment.

Additional lawsuits related to the derailment were filed in United States courts but were stayed as a result of the automatic stay arising from MM&A's United States bankruptcy proceeding. Arrow was named as a defendant in 39 lawsuits pending in three different courts; however, these lawsuits were dismissed with prejudice upon disbursement of funds to the victims. The settlement of the bankruptcy proceedings and the dismissals of the Class Action Suit and United States lawsuits did not have a material impact on our consolidated results of operations after considering insurance.

Simplification Merger Lawsuits. On May 20, 2015, Lawrence G. Farber, a purported unitholder of Crestwood Midstream, filed a complaint in the Southern District of the United States, Houston Division, as a putative class action on behalf of Crestwood Midstream's unitholders, entitled Lawrence G. Farber, individually and on behalf of all others similarly situated v. Crestwood Midstream Partners LP, Crestwood Midstream GP LLC, Robert G. Phillips, Alvin Bledsoe, Michael G. France, Philip D. Gettig, Warren H. Gfellar, David Lumpkins, John J. Sherman, David Wood, Crestwood Equity Partners LP, Crestwood Equity GP LLC, CEQP ST Sub LLC, MGP GP, LLC, Crestwood Midstream Holdings LP, and Crestwood Gas Services GP LLC. This complaint alleges, among other things, that Crestwood Midstream's general partner breached its fiduciary duties, certain individual defendants breached their fiduciary duties of loyalty and due care, and that other defendants aided and abetted such breaches.

On July 21, 2015, Isaac Aron, another purported unitholder of the Crestwood Midstream, filed a complaint in the Southern District of the United States, Houston Division, as a putative class action on behalf of Crestwood Midstream's unitholders, entitled Isaac Aron, individually and on behalf of all others similarly situated vs. Robert G. Phillps, Alvin Bledsoe, Michael G. France, Philip D. Getting, Warren H. Gfeller, David Lumpkins, John J. Sherman, David Wood, Crestwood Midstream Partners, LP Crestwood Midstream Holdings LP, Crestwood Midstream GP LLC, Crestwood Gas Services GP, LLC, Crestwood Equity Partners LP, Crestwood Equity GP LLC, CEQP ST Sub LLC and MGP GP, LLC. The complaint alleges, among other things, that Crestwood Midstream's general partner and certain individual defendants violated Sections 14(a) and 20(a) of the Securities Exchange Act of 1934 and Rule 14a-9 by filing an alleged incomplete and misleading Form S-4 Registration Statement with the SEC.

On August 12, 2015, the defendants filed a motion to consolidate the Farber and Aron cases, which the court granted on September 4, 2015. Farber subsequently dismissed his claims against all the defendants on September 16, 2015. Aron filed a motion for temporary restraining order and requested an expedited preliminary injunction hearing, which had been scheduled for September 23, 2015. On September 22, 2015, however, the parties entered into a memorandum of understanding (MOU) with respect to a proposed settlement of the Aron lawsuit. The settlement contemplated by the MOU is subject to a number of conditions, including notice to the class, limited confirmatory discovery and final court approval of the settlement. A hearing is scheduled for October 7, 2016 regarding the plaintiff's motion to approve the settlement. The anticipated settlement of the MOU has not and will not have a material impact to our consolidated financial statements.

Property Taxes. Tres Palacios filed a lawsuit in Matagorda County for tax years 2011, 2012 and 2013 alleging that the Matagorda County Appraisal District (MCAD) assessed taxable value above the fair market value and on an unequal and non-uniform basis compared to other properties. In conjunction with its sale of Tres Palacios to Tres Holdings, Crestwood Equity retained liability for certain tax matters, including this litigation. In January 2015, Crestwood Equity received a refund related to the 2011 tax year at the conclusion of the litigation related to that tax year. For the 2012 and 2013 tax years, the MCAD asserted a taxable value that would result in property taxes of approximately $7 million for each of those years, while Tres Palacios asserted a taxable value that would result in property taxes of less than $2 million in each year. Tres Palacios paid approximately $8.6 million to Matagorda County in total for those two tax years. A bench trial was held in October 2015 related to the 2012 and 2013 tax years. In June 2016, the court issued a final judgment on the 2012 and 2013 property tax years which resulted in Crestwood Equity recording additional net property taxes (including interest and penalties) of approximately $3.5 million during the three months endedJune 30, 2016. Crestwood Equity has filed a motion for a new trial.

General. We are periodically involved in litigation proceedings. If we determine that a negative outcome is probable and the amount of loss is reasonably estimable, then we accrue the estimated amount. The results of litigation proceedings cannot be predicted with certainty. We could incur judgments, enter into settlements or revise our expectations regarding the outcome of certain matters, and such developments could have a material adverse effect on our results of operations or cash flows in the period in which the amounts are paid and/or accrued. As of June 30, 2016 and December 31, 2015, both CEQP and CMLP had less than $0.1 million accrued for outstanding legal matters. Based on currently available information, we believe it is remote that future costs related to known contingent liability exposures for which we can estimate will exceed current accruals by an amount that would have a material adverse impact on our consolidated financial statements. As we learn new facts concerning contingencies, we reassess our position both with respect to accrued liabilities and other potential exposures.

Any loss estimates are inherently subjective, based on currently available information, and are subject to management's judgment and various assumptions. Due to the inherently subjective nature of these estimates and the uncertainty and unpredictability surrounding the outcome of legal proceedings, actual results may differ materially from any amounts that have been accrued.

Regulatory Compliance

In the ordinary course of our business, we are subject to various laws and regulations. In the opinion of our management, compliance with current laws and regulations will not have a material effect on its results of operations, cash flows or financial condition.

Environmental Compliance

During 2014, we experienced three releases totaling approximately 28,000 barrels of produced water on our Arrow water gathering system located on the Fort Berthold Indian Reservation in North Dakota. We immediately notified the National Response Center, the Three Affiliated Tribes and numerous other regulatory authorities, and thereafter contained and cleaned up the releases completely and placed the impacted segments of these water lines back into service. In May 2015, we experienced a release of approximately 5,200 barrels of produced water on our Arrow water gathering system, immediately notified numerous regulatory authorities and other third parties, and thereafter contained and cleaned up the releases.  We will continue our remediation efforts to ensure the impacted lands are restored to their prior state. We believe these releases are insurable events under our policies, and we have notified our carriers of these events. We have not recorded an insurance receivable as of June 30, 2016.

We may potentially be subject to fines and penalties as a result of the water releases.  In October 2014, we received data requests from the Environmental Protection Agency (EPA) related to the 2014 water releases and we responded to the requests during the first half of 2015.  In April 2015, the EPA issued a Notice of Potential Violation (NOPV) under the Clean Water Act relating to the 2014 water releases. We responded to the NOPV in May 2015, and have commenced settlement discussions with the EPA concerning the NOPV. On March 3, 2015, we received a grand jury subpoena from the United States Attorney’s Office in Bismarck, North Dakota, seeking documents and information relating to the largest of the three 2014 water releases, and we provided the requested information during the second quarter of 2015. In August 2015, we received a notice of violation from the Three Affiliated Tribes' Environmental Division related to our 2014 produced water releases on the Fort Berthold Indian Reservation. The notice of violation imposes fines and requests reimbursements exceeding $1.1 million; however, the notice of violation was stayed on September 15, 2015, upon our posting of a performance bond for the amount contemplated by the notice and pending the outcome of ongoing settlement discussions with the regulatory agencies asserting jurisdiction over the 2014 produced water releases. We cannot predict what the outcome of these investigations will be.

Our operations are subject to stringent and complex laws and regulations pertaining to health, safety, and the environment. We are subject to laws and regulations at the federal, state and local levels that relate to air and water quality, hazardous and solid waste management and disposal and other environmental matters. The cost of planning, designing, constructing and operating our facilities must incorporate compliance with environmental laws and regulations and safety standards. Failure to comply with these laws and regulations may trigger a variety of administrative, civil and potentially criminal enforcement measures. At June 30, 2016 and December 31, 2015, our accrual of approximately $2.6 million and $1.7 million is based on our undiscounted estimate of amounts we will spend on compliance with environmental and other regulations, and any associated fines or penalties. We estimate that our potential liability for reasonably possible outcomes related to our environmental exposures (including the Arrow water releases described above) could range from approximately $2.6 million to $4.9 million at June 30, 2016.

Self-Insurance

We utilize third-party insurance subject to varying retention levels of self-insurance, which management considers prudent. Such self-insurance relates to losses and liabilities primarily associated with medical claims, workers' compensation claims and general, product, vehicle and environmental liability. At June 30, 2016 and December 31, 2015, CEQP's self-insurance reserves were $17.8 million and $17.2 million. We estimate that $11.3 million of this balance will be paid subsequent to June 30, 2017. As such, CEQP has classified $11.3 million in other long-term liabilities on its consolidated balance sheet at June 30, 2016. At June 30, 2016 and December 31, 2015, CMLP's self insurance reserves were $12.4 million and $11.4 million. CMLP estimates that $7.1 million of this balance will be paid subsequent to June 30, 2017. As such, CMLP has classified $7.1 million in other long-term liabilities on its consolidated balance sheet at June 30, 2016.

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Related Party Transactions

6 Months Ended

Jun. 30, 2016

Related Party Transactions [Abstract]

Related Party Transactions

Related Party Transactions

CEQP and CMLP enter into transactions with their affiliates within the ordinary course of business and the services are based on the same terms as non-affiliates, including gas gathering and processing services under long-term contracts, product purchases and various operating agreements.

In May 2016, Crestwood Midstream Operations, LLC (Crestwood Midstream Operations), our wholly-owned subsidiary and Stagecoach Gas entered into a management agreement under which Crestwood Midstream Operations will provide the management and operating services required by Stagecoach Gas' facilities. The initial term of the agreement will expire in May 2021, and is automatically extended for three-year periods unless otherwise terminated pursuant to the terms of the agreement. During the three and six months endedJune 30, 2016, we charged Stagecoach Gas $0.3 million under this agreement, which is reflected as operations and maintenance expenses charged by CEQP and CMLP in the table below.

The following table shows revenues, costs of product/services sold, general and administrative expenses and reimbursements of expenses from our affiliates for the three and six months endedJune 30, 2016 and 2015 (in millions):

	Three Months Ended					Six Months Ended
	June 30,					June 30,
	2016			2015		2016			2015
Gathering and processing revenues at CEQP and CMLP	$	0.7		$	1.1	$	1.4		$	2.1
Gathering and processing costs of product/services sold at CEQP and CMLP(1)	$	4.4		$	7.7	$	8.7		$	16.0
Operations and maintenance expenses charged by CEQP and CMLP	$	1.0		$	0.7	$	1.7		$	1.6
General and administrative expenses charged by CEQP to CMLP, net(2)	$	3.2		$	14.4	$	6.9		$	31.8
General and administrative expenses charged by (from) CEQP to Crestwood Holdings, net(3)	$	(0.2	)	$	0.1	$	(0.1	)	$	0.2

(1) Represents natural gas purchases from Sabine Oil and Gas Corporation.

(2) Includes $3.9 million and $8.4 million of net unit-based compensation charges allocated from CEQP to CMLP for the three and six months endedJune 30, 2016 and $2.2 million and $4.4 million for the three and six months endedJune 30, 2015. In addition, prior to the completion of the Simplification Merger, CEQP allocated general and administrative costs to CMLP. In conjunction with the Simplification Merger, CMLP shares common management, general and administrative and overhead costs with CEQP. During the three and six months endedJune 30, 2016, CMLP allocated $0.7 million and $1.5 million of general and administrative costs to CEQP.

(3) Includes $0.9 million unit-based compensation charges allocated from Crestwood Holdings to CEQP and CMLP during the three and six months ended2016.

The following table shows accounts receivable and accounts payable from our affiliates as of June 30, 2016 and December 31, 2015 (in millions):

	CEQP				CMLP
	June 30, 2016		December 31, 2015		June 30, 2016		December 31, 2015
Accounts receivable	$	2.1	$	1.7	$	2.1	$	1.7
Accounts payable	$	6.3	$	4.0	$	3.8	$	1.5

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Segments

6 Months Ended

Jun. 30, 2016

Segment Reporting [Abstract]

Segments

Segments

Financial Information

As discussed in Note 1, on September 30, 2015, the Company contributed 100% of its interest in Crestwood Operations to Crestwood Midstream and as a result, we modified our segments and our financial statements to reflect three operating and reportable segments: (i) gathering and processing operations; (ii) storage and transportation operations; and (iii) marketing, supply and logistics operations (formerly NGL and crude services operations). Consequently, the results of our Arrow operations are now reflected in our gathering and processing operations for all periods presented and our COLT and PRBIC operations are now reflected in our storage and transportation operations for all periods presented. These respective operations were previously included in our NGL and crude services operations. Our corporate operations include all general and administrative expenses that are not allocated to our reportable segments. For a further description of our operating and reporting segments, see Note 1. We assess the performance of our operating segments based on EBITDA, a non-GAAP financial measure, which is defined as income before income taxes, plus debt-related costs (net interest and debt expense and gain or loss on modification/extinguishment of debt) and depreciation, amortization and accretion expense.

Below is a reconciliation of CEQP's net loss to EBITDA (in millions):

	Three Months Ended						Six Months Ended
	June 30,						June 30,
	2016			2015			2016			2015
Net loss	$	(37.1	)	$	(296.0	)	$	(130.8	)	$	(277.9	)
Add:
Interest and debt expense, net	34.3			35.4			70.4			69.0
(Gain) loss on modification/extinguishment of debt	(10.0		)	17.1			(10.0		)	17.1
Provision (benefit) for income taxes	—			(0.3		)	—			0.1
Depreciation, amortization and accretion	64.4			74.8			126.7			149.0
EBITDA	$	51.6		$	(169.0	)	$	56.3		$	(42.7	)

The following tables summarize CEQP's reportable segment data for the three and six months endedJune 30, 2016 and 2015 (in millions). Included in earnings from unconsolidated affiliates below was approximately $4.4 million and $0.7 million of depreciation and amortization expense and gains (losses) on long-lived assets, net related to our equity investments for the three months endedJune 30, 2016 and 2015 and $7.0 million and $3.8 million for the six months endedJune 30, 2016 and 2015.

	Three Months Ended June 30, 2016
	Gathering and Processing		Storage and Transportation			Marketing, Supply and Logistics			Corporate			Total
Revenues	$	269.5	$	53.8		$	278.6		$	—		$	601.9
Intersegment revenues	30.6		1.1			(31.7		)	—			—
Costs of product/services sold	226.3		1.9			221.8			—			450.0
Operations and maintenance expense	20.9		8.5			15.6			—			45.0
General and administrative expense	—		—			—			28.9			28.9
Loss on long-lived assets	—		(32.7		)	—			—			(32.7		)
Earnings from unconsolidated affiliates, net	5.9		0.3			—			—			6.2
Other income, net	—		—			—			0.1			0.1
EBITDA	$	58.8	$	12.1		$	9.5		$	(28.8	)	$	51.6
Goodwill	$	45.9	$	31.2		$	172.4		$	—		$	249.5
Total assets	$	2,394.1	$	1,191.2		$	974.8		$	33.3		$	4,593.4
Purchases of property, plant and equipment	$	4.2	$	11.6		$	4.7		$	0.1		$	20.6

	Three Months Ended June 30, 2015
	Gathering and Processing			Storage and Transportation		Marketing, Supply and Logistics			Corporate			Total
Revenues	$	346.8		$	68.5	$	226.2		$	—		$	641.5
Intersegment revenues	33.8			—		(33.8		)	—			—
Costs of product/services sold	293.1			5.3		161.1			—			459.5
Operations and maintenance expense	22.3			5.9		15.7			—			43.9
General and administrative expense	—			—		—			30.6			30.6
Loss on long-lived assets	(0.6		)	—		—			—			(0.6		)
Goodwill impairment	(220.7		)	—		(60.3		)	—			(281.0		)
Earnings from unconsolidated affiliates, net	1.1			3.9		—			—			5.0
Other income, net	—			—		—			0.1			0.1
EBITDA	$	(155.0	)	$	61.2	$	(44.7	)	$	(30.5	)	$	(169.0	)
Purchases of property, plant and equipment	$	28.4		$	3.9	$	3.6		$	0.2		$	36.1

	Six Months Ended June 30, 2016
	Gathering and Processing			Storage and Transportation			Marketing, Supply and Logistics			Corporate			Total
Revenues	$	508.4		$	113.2		$	516.3		$	—		$	1,137.9
Intersegment revenues	51.1			1.5			(52.6		)	—			—
Costs of product/services sold	406.1			4.8			402.5			—			813.4
Operations and maintenance expense	38.7			15.7			32.4			—			86.8
General and administrative expense	—			—			—			51.9			51.9
Loss on long-lived assets	—			(32.7		)	—			—			(32.7		)
Goodwill impairment	(8.6		)	(13.7		)	(87.4		)	—			(109.7		)
Earnings from unconsolidated affiliates, net	11.0			1.7			—			—			12.7
Other income, net	—			—			—			0.2			0.2
EBITDA	$	117.1		$	49.5		$	(58.6	)	$	(51.7	)	$	56.3
Goodwill	$	45.9		$	31.2		$	172.4		$	—		$	249.5
Total assets	$	2,394.1		$	1,191.2		$	974.8		$	33.3		$	4,593.4
Purchases of property, plant and equipment	$	48.5		$	14.9		$	11.8		$	1.0		$	76.2

	Six Months Ended June 30, 2015
	Gathering and Processing			Storage and Transportation			Marketing, Supply and Logistics			Corporate			Total
Revenues	$	697.1		$	136.1		$	539.8		$	—		$	1,373.0
Intersegment revenues	43.9			—			(43.9		)	—			—
Costs of product/services sold	559.8			10.6			418.8			—			989.2
Operations and maintenance expense	46.4			12.3			35.8			—			94.5
General and administrative expense	—			—			—			58.1			58.1
Goodwill impairment	(220.7		)	—			(60.3		)	—			(281.0		)
Loss on long-lived assets	(0.9		)	(0.7		)	—			—			(1.6		)
Earnings from unconsolidated affiliates, net	3.6			4.8			—			—			8.4
Other income, net	—			—			—			0.3			0.3
EBITDA	$	(83.2	)	$	117.3		$	(19.0	)	$	(57.8	)	$	(42.7	)
Purchases of property, plant and equipment	$	64.6		$	8.0		$	10.5		$	0.4		$	83.5

Below is a reconciliation of CMLP's net loss to EBITDA (in millions):

	Three Months Ended						Six Months Ended
	June 30,						June 30,
	2016			2015			2016			2015
Net loss	$	(35.6	)	$	(72.8	)	$	(130.9	)	$	(43.7	)
Add:
Interest and debt expense, net	34.3			32.6			70.4			62.5
(Gain) loss on modification/extinguishment of debt	(10.0		)	17.1			(10.0		)	17.1
Provision for income taxes	0.2			0.1			—			0.5
Depreciation, amortization and accretion	67.1			69.5			132.0			138.3
EBITDA	$	56.0		$	46.5		$	61.5		$	174.7

The following tables summarize CMLP's reportable segment data for the three and six months endedJune 30, 2016 and 2015 (in millions). Included in earnings from unconsolidated affiliates below was approximately $4.4 million and $0.7 million of depreciation and amortization expense and gains (losses) on long-lived assets, net related to our equity investments for the three months ended June 30, 2016 and 2015 and $7.0 million and $3.8 million for the six months ended June 30, 2016 and 2015.

	Three Months Ended June 30, 2016
	Gathering and Processing		Storage and Transportation			Marketing, Supply and Logistics			Corporate			Total
Revenues	$	269.5	$	53.8		$	278.6		$	—		$	601.9
Intersegment revenues	30.6		1.1			(31.7		)	—			—
Costs of product/services sold	226.3		1.9			221.8			—			450.0
Operations and maintenance expense	20.9		4.9			15.6			—			41.4
General and administrative expense	—		—			—			28.0			28.0
Loss on long-lived assets	—		(32.7		)	—			—			(32.7		)
Earnings from unconsolidated affiliates, net	5.9		0.3			—			—			6.2
EBITDA	$	58.8	$	15.7		$	9.5		$	(28.0	)	$	56.0
Goodwill	$	45.9	$	31.2		$	172.4		$	—		$	249.5
Total assets	$	2,603.3	$	1,188.9		$	974.8		$	18.9		$	4,785.9
Purchases of property, plant and equipment	$	4.2	$	11.6		$	4.7		$	0.1		$	20.6

	Three Months Ended June 30, 2015
	Gathering and Processing			Storage and Transportation			Marketing, Supply and Logistics			Corporate			Total
Revenues	$	346.8		$	68.5		$	226.2		$	—		$	641.5
Intersegment revenues	33.8			—			(33.8		)	—			—
Costs of product/services sold	293.1			5.3			161.1			—			459.5
Operations and maintenance expense	22.3			5.9			15.7			—			43.9
General and administrative expense	—			—			—			27.3			27.3
Goodwill impairment	(8.3		)	—			(60.3		)	—			(68.6		)
Loss on long-lived assets	(0.6		)	(0.1		)	—			—			(0.7		)
Earnings from unconsolidated affiliates, net	1.1			3.9			—			—			5.0
EBITDA	$	57.4		$	61.1		$	(44.7	)	$	(27.3	)	$	46.5
Purchases of property, plant and equipment	$	28.4		$	3.9		$	3.6		$	0.2		$	36.1

	Six Months Ended June 30, 2016
	Gathering and Processing			Storage and Transportation			Marketing, Supply and Logistics			Corporate			Total
Revenues	$	508.4		$	113.2		$	516.3		$	—		$	1,137.9
Intersegment revenues	51.1			1.5			(52.6		)	—			—
Costs of product/services sold	406.1			4.8			402.5			—			813.4
Operations and maintenance expense	38.7			12.0			32.4			—			83.1
General and administrative expense	—			—			—			50.2			50.2
Goodwill impairment	(8.6		)	(13.7		)	(87.4		)	—			(109.7		)
Loss on long-lived assets	—			(32.7		)	—			—			(32.7		)
Earnings from unconsolidated affiliates, net	11.0			1.7			—			—			12.7
EBITDA	$	117.1		$	53.2		$	(58.6	)	$	(50.2	)	$	61.5
Goodwill	$	45.9		$	31.2		$	172.4		$	—		$	249.5
Total assets	$	2,603.3		$	1,188.9		$	974.8		$	18.9		$	4,785.9
Purchases of property, plant and equipment	$	48.5		$	14.9		$	11.8		$	1.0		$	76.2

	Six Months Ended June 30, 2015
	Gathering and Processing			Storage and Transportation			Marketing, Supply and Logistics			Corporate			Total
Revenues	$	697.1		$	136.1		$	539.8		$	—		$	1,373.0
Intersegment revenues	43.9			—			(43.9		)	—			—
Costs of product/services sold	559.8			10.6			418.8			—			989.2
Operations and maintenance expense	46.4			12.3			35.8			—			94.5
General and administrative expense	—			—			—			52.9			52.9
Goodwill impairment	(8.3		)	—			(60.3		)	—			(68.6		)
Loss on long-lived assets	(0.9		)	(0.6		)	—			—			(1.5		)
Earnings from unconsolidated affiliates, net	3.6			4.8			—			—			8.4
EBITDA	$	129.2		$	117.4		$	(19.0	)	$	(52.9	)	$	174.7
Purchases of property, plant and equipment	$	64.6		$	8.0		$	10.5		$	0.4		$	83.5

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Condensed Consolidating Financial Information

6 Months Ended

Jun. 30, 2016

Condensed Financial Information of Parent Company Only Disclosure [Abstract]

Condensed Consolidating Financial Information

Condensed Consolidating Financial Information

Crestwood Midstream is a holding company (Parent) and owns no operating assets and has no significant operations independent of its subsidiaries. Obligations under Crestwood Midstream's senior notes and its credit facility are jointly and severally guaranteed by substantially all of its subsidiaries, except for Crestwood Delaware Basin LLC, Crestwood Niobrara, Crestwood Northeast, PRBIC and Tres Holdings and their respective subsidiaries (collectively, Non-Guarantor Subsidiaries). Crestwood Midstream Finance Corp., the co-issuer of its senior notes, is Crestwood Midstream's 100% owned subsidiary and has no material assets, operations, revenues or cash flows other than those related to its service as co-issuer of the Crestwood Midstream senior notes.

The tables below present condensed consolidating financial statements for Crestwood Midstream as parent on a stand-alone, unconsolidated basis, and Crestwood Midstream's combined guarantor and combined non-guarantor subsidiaries as of June 30, 2016 and December 31, 2015, and for the three and six months endedJune 30, 2016 and 2015.  The financial information may not necessarily be indicative of the results of operations, cash flows or financial position had the subsidiaries operated as independent entities.

Crestwood Midstream Partners LP
Condensed Consolidating Balance Sheet
June 30, 2016
(in millions)
	Parent		Guarantor Subsidiaries		Non- Guarantor Subsidiaries		Eliminations			Consolidated
Assets
Current assets:
Cash	$	0.2	$	—	$	—	$	—		$	0.2
Accounts receivable	—		242.4		1.9		—			244.3
Inventory	—		43.5		—		—			43.5
Assets held for sale	—		55.0		—		—			55.0
Other current assets	—		19.8		—		—			19.8
Total current assets	0.2		360.7		1.9		—			362.8
Property, plant and equipment, net	—		2,355.9		—		—			2,355.9
Goodwill and intangible assets, net	—		965.2		—		—			965.2
Investment in consolidated affiliates	4,310.1		—		—		(4,310.1		)	—
Investment in unconsolidated affiliates	—		—		1,099.1		—			1,099.1
Other assets	—		2.9		—		—			2.9
Total assets	$	4,310.3	$	3,684.7	$	1,101.0	$	(4,310.1	)	$	4,785.9
Liabilities and partners' capital
Current liabilities:
Accounts payable	$	—	$	161.8	$	—	$	—		$	161.8
Other current liabilities	23.4		82.9		—		—			106.3
Total current liabilities	23.4		244.7		—		—			268.1
Long-term liabilities:
Long-term debt, less current portion	1,580.1		1.5		—		—			1,581.6
Other long-term liabilities	—		40.9		—		—			40.9
Deferred income taxes	—		0.7		—		—			0.7
Partners' capital	2,706.8		3,396.9		913.2		(4,310.1		)	2,706.8
Interest of non-controlling partners in subsidiaries	—		—		187.8		—			187.8
Total partners' capital	2,706.8		3,396.9		1,101.0		(4,310.1		)	2,894.6
Total liabilities and partners' capital	$	4,310.3	$	3,684.7	$	1,101.0	$	(4,310.1	)	$	4,785.9

Crestwood Midstream Partners LP
Condensed Consolidating Balance Sheet
December 31, 2015
(in millions)
	Parent		Guarantor Subsidiaries		Non- Guarantor Subsidiaries		Eliminations			Consolidated
Assets
Current assets:
Cash	$	0.1	$	—	$	—	$	—		$	0.1
Accounts receivable	—		236.0		0.5		—			236.5
Inventory	—		44.5		—		—			44.5
Other current assets	—		52.5		—		—			52.5
Total current assets	0.1		333.0		0.5		—			333.6
Property, plant and equipment, net	—		3,525.7		—		—			3,525.7
Goodwill and intangible assets, net	—		1,846.9		—		—			1,846.9
Investment in consolidated affiliates	5,506.8		—		—		(5,506.8		)	—
Investment in unconsolidated affiliates	—		—		254.3		—			254.3
Other assets	—		3.1		—		—			3.1
Total assets	$	5,506.9	$	5,708.7	$	254.8	$	(5,506.8	)	$	5,963.6
Liabilities and partners' capital
Current liabilities:
Accounts payable	$	—	$	141.3	$	0.1	$	—		$	141.4
Other current liabilities	26.4		85.2		—		—			111.6
Total current liabilities	26.4		226.5		0.1		—			253.0
Long-term liabilities:
Long-term debt, less current portion	2,498.9		2.9		—		—			2,501.8
Other long-term liabilities	—		43.3		—		—			43.3
Deferred income taxes	—		0.4		—		—			0.4
Partners' capital	2,981.6		5,435.6		71.2		(5,506.8		)	2,981.6
Interest of non-controlling partners in subsidiaries	—		—		183.5		—			183.5
Total partners' capital	2,981.6		5,435.6		254.7		(5,506.8		)	3,165.1
Total liabilities and partners' capital	$	5,506.9	$	5,708.7	$	254.8	$	(5,506.8	)	$	5,963.6

Crestwood Midstream Partners LP
Condensed Consolidating Statement of Operations
Three Months Ended June 30, 2016
(in millions)
	Parent			Guarantor Subsidiaries			Non- Guarantor Subsidiaries		Eliminations			Consolidated
Revenues	$	—		$	601.9		$	—	$	—		$	601.9
Costs of product/services sold	—			450.0			—		—			450.0
Expenses:
Operations and maintenance	—			41.4			—		—			41.4
General and administrative	23.2			4.8			—		—			28.0
Depreciation, amortization and accretion	—			67.1			—		—			67.1
	23.2			113.3			—		—			136.5
Other operating expense:
Loss on long-lived assets, net	—			(32.7		)	—		—			(32.7		)
Goodwill impairment	—			—			—		—			—
Operating income (loss)	(23.2		)	5.9			—		—			(17.3		)
Earnings from unconsolidated affiliates, net	—			—			6.2		—			6.2
Interest and debt expense, net	(34.3		)	—			—		—			(34.3		)
Gain on modification/extinguishment of debt	10.0			—			—		—			10.0
Equity in net income (loss) of subsidiary	11.9			—			—		(11.9		)	—
Income (loss) before income taxes	(35.6		)	5.9			6.2		(11.9		)	(35.4		)
Provision for income taxes	—			0.2			—		—			0.2
Net income (loss)	(35.6		)	5.7			6.2		(11.9		)	(35.6		)
Net income attributable to non-controlling partners in subsidiaries	—			—			6.0		—			6.0
Net income (loss) attributable to Crestwood Midstream Partners LP	$	(35.6	)	$	5.7		$	0.2	$	(11.9	)	$	(41.6	)

Crestwood Midstream Partners LP
Condensed Consolidating Statement of Operations
Three Months Ended June 30, 2015
(in millions)
	Parent			Guarantor Subsidiaries			Non- Guarantor Subsidiaries			Eliminations		Consolidated
Revenues	$	—		$	641.5		$	—		$	—	$	641.5
Costs of product/services sold	—			459.5			—			—		459.5
Expenses:
Operations and maintenance	—			43.9			—			—		43.9
General and administrative	16.4			10.9			—			—		27.3
Depreciation, amortization and accretion	0.9			68.6			—			—		69.5
	17.3			123.4			—			—		140.7
Other operating expense:
Loss on long-lived assets, net	—			(0.7		)	—			—		(0.7		)
Goodwill Impairment	—			(68.6		)	—			—		(68.6		)
Operating loss	(17.3		)	(10.7		)	—			—		(28.0		)
Earnings from unconsolidated affiliates, net	—			—			5.0			—		5.0
Interest and debt expense, net	(32.6		)	—			—			—		(32.6		)
Loss on modification/extinguishment of debt	(17.1		)	—			—			—		(17.1		)
Equity in net income (loss) of subsidiary	(5.8		)	—			—			5.8		—
Income (loss) before income taxes	(72.8		)	(10.7		)	5.0			5.8		(72.7		)
Provision for income taxes	—			0.1			—			—		0.1
Net income (loss)	(72.8		)	(10.8		)	5.0			5.8		(72.8		)
Net income attributable to non-controlling partners in subsidiaries	—			—			5.7			—		5.7
Net income (loss) attributable to Crestwood Midstream Partners LP	(72.8		)	(10.8		)	(0.7		)	5.8		(78.5		)
Net income attributable to Class A preferred units	7.5			—			—			—		7.5
Net income (loss) attributable to partners	$	(80.3	)	$	(10.8	)	$	(0.7	)	$	5.8	$	(86.0	)

Crestwood Midstream Partners LP
Condensed Consolidating Statement of Operations
Six Months Ended June 30, 2016
(in millions)
	Parent			Guarantor Subsidiaries			Non- Guarantor Subsidiaries		Eliminations		Consolidated
Revenues	$	—		$	1,137.9		$	—	$	—	$	1,137.9
Costs of product/services sold	—			813.4			—		—		813.4
Expenses:
Operations and maintenance	—			83.1			—		—		83.1
General and administrative	40.9			9.3			—		—		50.2
Depreciation, amortization and accretion	—			132.0			—		—		132.0
	40.9			224.4			—		—		265.3
Other operating expense:
Loss on long-lived assets, net	—			(32.7		)	—		—		(32.7		)
Goodwill impairment	—			(109.7		)	—		—		(109.7		)
Operating loss	(40.9		)	(42.3		)	—		—		(83.2		)
Earnings from unconsolidated affiliates, net	—			—			12.7		—		12.7
Interest and debt expense, net	(70.4		)	—			—		—		(70.4		)
Gain on modification/extinguishment of debt	10.0			—			—		—		10.0
Equity in net income (loss) of subsidiary	(29.6		)	—			—		29.6		—
Net income (loss)	(130.9		)	(42.3		)	12.7		29.6		(130.9		)
Net income attributable to non-controlling partners in subsidiaries	—			—			11.9		—		11.9
Net income (loss) attributable to Crestwood Midstream Partners LP	$	(130.9	)	$	(42.3	)	$	0.8	$	29.6	$	(142.8	)

Crestwood Midstream Partners LP
Condensed Consolidating Statement of Operations
Six Months Ended June 30, 2015
(in millions)
	Parent			Guarantor Subsidiaries			Non- Guarantor Subsidiaries			Eliminations			Consolidated
Revenues	$	—		$	1,373.0		$	—		$	—		$	1,373.0
Costs of product/services sold	—			989.2			—			—			989.2
Expenses:
Operations and maintenance	—			94.5			—			—			94.5
General and administrative	29.8			23.1			—			—			52.9
Depreciation, amortization and accretion	1.1			137.2			—			—			138.3
	30.9			254.8			—			—			285.7
Other operating expense:
Loss on long-lived assets, net	—			(1.5		)	—			—			(1.5		)
Goodwill Impairment	—			(68.6		)	—			—			(68.6		)
Operating income (loss)	(30.9		)	58.9			—			—			28.0
Earnings from unconsolidated affiliates, net	—			—			8.4			—			8.4
Interest and debt expense, net	(62.5		)	—			—			—			(62.5		)
Loss on modification/extinguishment of debt	(17.1		)	—			—			—			(17.1		)
Equity in net income (loss) of subsidiary	66.8			—			—			(66.8		)	—
Income (loss) before income taxes	(43.7		)	58.9			8.4			(66.8		)	(43.2		)
Provision for income taxes	—			0.5			—			—			0.5
Net income (loss)	(43.7		)	58.4			8.4			(66.8		)	(43.7		)
Net income attributable to non-controlling partners in subsidiaries	—			—			11.3			—			11.3
Net income (loss) attributable to Crestwood Midstream Partners LP	(43.7		)	58.4			(2.9		)	(66.8		)	(55.0		)
Net income attributable to Class A preferred units	16.7			—			—			—			16.7
Net income (loss) attributable to partners	$	(60.4	)	$	58.4		$	(2.9	)	$	(66.8	)	$	(71.7	)

Crestwood Midstream Partners LP
Condensed Consolidating Statement of Cash Flows
Six Months Ended June 30, 2016
(in millions)
	Parent			Guarantor Subsidiaries			Non- Guarantor Subsidiaries			Eliminations			Consolidated
Cash flows from operating activities:	$	(110.9	)	$	296.5		$	10.4		$	—		$	196.0
Cash flows from investing activities:
Purchases of property, plant and equipment	(1.0		)	(75.2		)	—			—			(76.2		)
Investment in unconsolidated affiliates	—			—			(5.5		)	—			(5.5		)
Proceeds from the sale of assets	—			942.0			—			—			942.0
Capital distributions from unconsolidated affiliates	—			—			5.5			—			5.5
Capital distributions from consolidated affiliates	2.8			—			—			(2.8		)	—
Net cash provided by (used in) investing activities	1.8			866.8			—			(2.8		)	865.8
Cash flows from financing activities:
Proceeds from the issuance of long-term debt	1,078.8			—			—			—			1,078.8
Principal payments on long-term debt	(1,986.8		)	(0.7		)	—			—			(1,987.5		)
Payments on capital leases	—			(0.9		)	—			—			(0.9		)
Payments for debt-related deferred costs	(3.3		)	—			—			—			(3.3		)
Distributions paid	(140.6		)	—			(7.6		)	—			(148.2		)
Distributions to parent	—			—			(2.8		)	2.8			—
Taxes paid for unit-based compensation vesting	—			(0.6		)	—			—			(0.6		)
Change in intercompany balances	1,161.1			(1,161.1		)	—			—			—
Net cash provided by (used in) financing activities	109.2			(1,163.3		)	(10.4		)	2.8			(1,061.7		)
Net change in cash	0.1			—			—			—			0.1
Cash at beginning of period	0.1			—			—			—			0.1
Cash at end of period	$	0.2		$	—		$	—		$	—		$	0.2

Crestwood Midstream Partners LP
Condensed Consolidating Statement of Cash Flows
Six Months Ended June 30, 2015
(in millions)
	Parent			Guarantor Subsidiaries			Non- Guarantor Subsidiaries			Eliminations			Consolidated
Cash flows from operating activities:	$	(89.1	)	$	286.6		$	6.0		$	—		$	203.5
Cash flows from investing activities:
Purchases of property, plant and equipment	(0.4		)	(83.1		)	—			—			(83.5		)
Investment in unconsolidated affiliates	—			—			(27.8		)	—			(27.8		)
Capital distributions from unconsolidated affiliates	—			—			1.0			—			1.0
Proceeds from the sale of assets	—			2.1			—			—			2.1
Capital contributions to consolidated affiliates	(24.6		)	—			—			24.6			—
Net cash provided by (used in) investing activities	(25.0		)	(81.0		)	(26.8		)	24.6			(108.2		)
Cash flows from financing activities:
Proceeds from the issuance of long-term debt	1,865.1			—			—			—			1,865.1
Principal payments on long-term debt	(1,713.2		)	—			—			—			(1,713.2		)
Payments on capital leases	(0.9		)	(0.3		)	—			—			(1.2		)
Payments for debt-related deferred costs	(11.7		)	—			—			—			(11.7		)
Financing fees paid for early debt redemption	(13.6		)	—			—			—			(13.6		)
Distributions paid	(221.4		)	—			(3.8		)	—			(225.2		)
Contributions from parent	—			—			24.6			(24.6		)	—
Taxes paid for unit-based compensation vesting	—			(2.1		)	—			—			(2.1		)
Change in intercompany balances	210.0			(210.0		)	—			—			—
Other	(0.2		)	—			—			—			(0.2		)
Net cash provided by (used in) financing activities	114.1			(212.4		)	20.8			(24.6		)	(102.1		)
Net change in cash	—			(6.8		)	—			—			(6.8		)
Cash at beginning of period	—			7.6			—			—			7.6
Cash at end of period	$	—		$	0.8		$	—		$	—		$	0.8

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Basis of Presentation and Summary of Significant Accounting Policies (Policies)

6 Months Ended

Jun. 30, 2016

Accounting Policies [Abstract]

Significant Accounting Policies

Significant Accounting Policies

There were no material changes in our significant accounting policies from those described in our 2015 Annual Report on Form 10-K.

New Accounting Pronouncements Issued But Not Yet Adopted

New Accounting Pronouncements Issued But Not Yet Adopted

As of June 30, 2016, the following accounting standards had not yet been adopted by us:

In May 2014, the Financial Accounting Standards Board (FASB) issued ASU 2014-09, Revenue from Contracts with Customers, which outlines a single comprehensive model for entities to use in accounting for revenue arising from contracts with customers and supersedes current revenue recognition guidance. We expect to adopt the provisions of this standard effective January 1, 2018 and are currently evaluating the method by which we will adopt the standard and the impact that this standard will have on our consolidated financial statements.

In February 2016, the FASB issued ASU 2016-02, Leases (Topic 842), which revises the accounting for leases by requiring certain leases to be recognized as assets and liabilities on the balance sheet, and requiring companies to disclose additional information about their leasing arrangements. We expect to adopt the provisions of this standard effective January 1, 2019 and are currently evaluating the impact that this standard will have on our consolidated financial statements.

In March 2016, the FASB issued ASU 2016-09, Compensation - Stock Compensation (Topic 718):Improvements to Employee Share-Based Payment Accounting, which is intended to improve the accounting for employee share-based payments. The ASU simplifies several aspects of the accounting for share-based payment award transactions, including the classification of awards as either equity or liabilities and presentation on the statement of cash flows. We expect to adopt the provisions of this standard effective January 1, 2017 and are currently evaluating the impact that this standard may have on our consolidated financial statements.

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Basis of Presentation and Summary of Significant Accounting Policies Goodwill (Tables)

6 Months Ended

Jun. 30, 2016

Goodwill and Intangible Assets Disclosure [Abstract]

Schedule of Goodwill

	Goodwill at		Goodwill Impairments during the  Six Months Ended		Deconsolidation of NE S&T Assets at		Goodwill at
	December 31, 2015		June 30, 2016		June 30, 2016		June 30, 2016
Gathering and Processing
Marcellus	$	8.6	$	8.6	$	—	$	—
Arrow	45.9		—		—		45.9
Storage and Transportation
Northeast Storage and Transportation	726.3		—		726.3		—
COLT	44.9		13.7		—		31.2
Marketing, Supply and Logistics					—
Supply and Logistics	167.2		65.5		—		101.7
Storage and Terminals	50.5		14.1		—		36.4
US Salt	12.6		—		—		12.6
Trucking	29.5		7.8		—		21.7
Total	$	1,085.5	$	109.7	$	726.3	$	249.5

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Certain Balance Sheet Information (Tables)

6 Months Ended

Jun. 30, 2016

Balance Sheet Related Disclosures [Abstract]

Schedule of Accrued Liabilities

Accrued expenses and other liabilities consisted of the following at June 30, 2016 and December 31, 2015 (in millions):

	CEQP				CMLP
	June 30,		December 31,		June 30,		December 31,
	2016		2015		2016		2015
Accrued expenses	$	35.5	$	46.4	$	33.8	$	44.1
Accrued property taxes	12.3		4.8		7.3		4.8
Accrued product purchases payable	2.8		1.5		2.8		1.5
Tax payable	0.6		0.5		0.6		0.5
Interest payable	23.2		26.2		23.2		26.2
Accrued additions to property, plant and equipment	2.9		10.4		2.9		10.4
Capital leases	1.3		1.6		1.3		1.6
Deferred revenue	22.6		14.2		22.6		14.2
Total accrued expenses and other liabilities	$	101.2	$	105.6	$	94.5	$	103.3

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Investments in Unconsolidated Affiliates (Tables)

6 Months Ended

Jun. 30, 2016

Equity Method Investments and Joint Ventures [Abstract]

Equity Method Investments

Our net investments in and earnings from our unconsolidated affiliates are as follows (in millions, unless otherwise stated):

	Ownership Percentage			Investment				Earnings (Loss) from Unconsolidated Affiliates
	June 30,			June 30,		December 31,		Three Months Ended June 30,					Six Months Ended June 30,
	2016			2016		2015		2016			2015		2016			2015
Stagecoach Gas Services LLC(1)	50.00	%		$	846.3	$	—	$	2.3		$	—	$	2.3		$	—
Jackalope Gas Gathering Services, L.L.C.(2)	50.00	%	(3)	201.3		202.4		5.9			1.1		11.0			3.6
Tres Palacios Holdings LLC(4)	50.01	%		36.7		36.8		(2.3		)	0.6		(1.5		)	1.5
Powder River Basin Industrial Complex, LLC(5)	50.01	%		14.8		15.1		0.3			3.3		0.9			3.3
Total				$	1,099.1	$	254.3	$	6.2		$	5.0	$	12.7		$	8.4

(1) As of June 30, 2016, our equity in the underlying net assets of Stagecoach Gas exceeded our investment balance by approximately $50.8 million. Our Stagecoach Gas investment is included in our storage and transportation segment.

(2) As of June 30, 2016, our equity in the underlying net assets of Jackalope Gas Gathering Services, L.L.C. (Jackalope) exceeded our investment balance by approximately $0.8 million. We amortize this amount over 20 years, which represents the life of Jackalope’s gathering agreement with Chesapeake Energy Corporation (Chesapeake), and we reflect the amortization as an increase in our earnings from unconsolidated affiliates. We recorded amortization of less than $0.1 million for both the three and six months endedJune 30, 2016 and $0.7 million and $1.5 million for the three and six months endedJune 30, 2015. Our Jackalope investment is included in our gathering and processing segment.

(3) Excludes non-controlling interests related to our investment in Jackalope. See Note 9 for a further discussion of our non-controlling interest related to our investment in Jackalope.

(4) As of June 30, 2016, our equity in the underlying net assets of Tres Palacios Holdings LLC (Tres Holdings) exceeded our investment balance by approximately $28.5 million. We amortize this amount over the life of the Tres Palacios Gas Storage LLC (Tres Palacios) sublease agreement, and we reflect the amortization as an increase in our earnings from unconsolidated affiliates. We recorded amortization of $0.3 million for the three months endedJune 30, 2016 and 2015, and $0.6 million for the six months endedJune 30, 2016 and 2015. Our Tres Holdings investment is included in our storage and transportation segment.

(5) As of June 30, 2016, our equity in the underlying net assets of PRBIC exceeded our investment balance by approximately $22.6 million. We amortize a portion of this amount over the life of PRBIC's property, plant and equipment and its agreement with Chesapeake, and we reflect the amortization as an increase in our earnings from unconsolidated affiliates. Approximately $10.6 million of this excess amount relates to goodwill and, as such, is not subject to amortization. We recorded amortization of approximately $0.4 million and $0.8 million for the three and six months endedJune 30, 2016. During the three and six months ended June 30, 2015, we recorded additional equity earnings of approximately $3.2 million related to a gain associated with the adjustment of our member's capital account by our equity investee. Our PRBIC investment is included in our storage and transportation segment.

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Risk Management (Tables)

6 Months Ended

Jun. 30, 2016

Risk Management - Notional Amounts and Terms of Companys Derivative Financial Instruments [Abstract]

Notional Amounts And Terms Of Company's Derivative Financial Instruments

The notional amounts and terms of our derivative financial instruments include the following at June 30, 2016 and December 31, 2015 (in millions):

	June 30, 2016		December 31, 2015
	Fixed Price Payor	Fixed Price Receiver	Fixed Price Payor	Fixed Price Receiver
Propane, crude and heating oil (barrels)	12.4	13.8	9.1	10.9

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Fair Value Measurements (Tables)

6 Months Ended

Jun. 30, 2016

Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]

Schedule of Carrying Values and Estimated Fair Values of Debt Instruments

We estimate the fair value of our senior notes primarily based on quoted market prices for the same or similar issuances (representing a Level 2 fair value measurement). The following table reflects the carrying value and fair value of our CMLP senior notes (in millions):

	June 30, 2016				December 31, 2015
	Carrying  Amount		Fair Value		Carrying  Amount		Fair Value
Crestwood Midstream 2020 Senior Notes	$	340.8	$	319.9	$	503.3	$	382.3
Crestwood Midstream 2022 Senior Notes	$	436.4	$	400.8	$	600.0	$	437.4
Crestwood Midstream 2023 Senior Notes	$	700.0	$	645.8	$	700.0	$	491.8

Assets And Liabilities Measured At Fair Value On Recurring Basis

The following tables set forth by level within the fair value hierarchy, our financial instruments that were accounted for at fair value on a recurring basis at June 30, 2016 and December 31, 2015 (in millions):

	June 30, 2016
	Fair Value of Derivatives
	Level 1		Level 2		Level 3		Gross Fair Value		Contract Netting(1)			Collateral/Margin Received or Paid			Recorded in Balance Sheet
Assets
Assets from price risk management	$	0.2	$	44.0	$	—	$	44.2	$	(28.9	)	$	(5.8	)	$	9.5
Suburban Propane Partners, L.P. units(2)	4.7		—		—		4.7		—			—			4.7
Total assets at fair value	$	4.9	$	44.0	$	—	$	48.9	$	(28.9	)	$	(5.8	)	$	14.2
Liabilities
Liabilities from price risk management	$	0.2	$	37.5	$	—	$	37.7	$	(28.9	)	$	2.1		$	10.9
Total liabilities at fair value	$	0.2	$	37.5	$	—	$	37.7	$	(28.9	)	$	2.1		$	10.9
	December 31, 2015
	Fair Value of Derivatives
	Level 1		Level 2		Level 3		Gross Fair Value		Contract Netting(1)			Collateral/Margin Received or Paid			Recorded in Balance Sheet
Assets
Assets from price risk management	$	0.5	$	57.8	$	—	$	58.3	$	(13.7	)	$	(12.0	)	$	32.6
Suburban Propane Partners, L.P. units(2)	3.4		—		—		3.4		—			—			3.4
Total assets at fair value	$	3.9	$	57.8	$	—	$	61.7	$	(13.7	)	$	(12.0	)	$	36.0
Liabilities
Liabilities from price risk management	$	0.2	$	41.3	$	—	$	41.5	$	(13.7	)	$	(20.4	)	$	7.4
Total liabilities at fair value	$	0.2	$	41.3	$	—	$	41.5	$	(13.7	)	$	(20.4	)	$	7.4

(1) Amounts represent the impact of legally enforceable master netting agreements that allow us to settle positive and negative positions as well as cash collateral held or placed with the same counterparties.

(2) Amount is reflected in other assets on CEQP's consolidated balance sheets.

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Long-Term Debt (Tables)

6 Months Ended

Jun. 30, 2016

Text Block [Abstract]

Components Of Long-Term Debt

Long-term debt consisted of the following at June 30, 2016 and December 31, 2015 (in millions):

	June 30, 2016		December 31, 2015
Credit Facility	$	139.0	$	735.0
2020 Senior Notes	338.8		500.0
Fair value adjustment of 2020 Senior Notes	2.0		3.3
2022 Senior Notes	436.4		600.0
2023 Senior Notes	700.0		700.0
Other	3.9		5.3
Less: deferred financing costs, net	37.6		40.9
Total Crestwood Midstream debt	1,582.5		2,502.7
Other	—		0.2
Total Crestwood Equity debt	1,582.5		2,502.9
Less: current portion	0.9		1.1
Total long-term debt, less current portion	$	1,581.6	$	2,501.8

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Partners' Capital (Tables)

6 Months Ended

Jun. 30, 2016

Distribution Made to Limited Partner [Line Items]

Schedule of Distributions Made to Members or Limited Partners, by Distribution

A summary of CEQP's limited partner quarterly cash distributions for the six months endedJune 30, 2016 and 2015 is presented below:

Record Date	Payment Date	Per Unit Rate		Cash Distributions (in millions)
2016
February 5, 2016	February 12, 2016	$	1.375	$	95.6
May 6, 2016	May 13, 2016	0.60		41.4
				$	137.0
2015
February 6, 2015	February 13, 2015	$	1.375	$	25.8
May 8, 2015	May 15, 2015	1.375		25.7
				$	51.5

Components of Net Income (Loss) Attributable to Non-Controlling Partners

The components of net income (loss) attributable to non-controlling partners for the three and six months endedJune 30, 2016 and 2015, are as follows (in millions):

	Three Months Ended					Six Months Ended
	June 30,					June 30,
	2016		2015			2016		2015
Crestwood Niobrara preferred interests	$	6.0	$	5.7		$	11.9	$	11.3
CMLP net income attributable to non-controlling partners	6.0		5.7			11.9		11.3
Crestwood Midstream limited partner interests	—		(269.2		)	—		(274.2		)
Crestwood Midstream Class A preferred units	—		7.5			—		16.7
CEQP net income (loss) attributable to non-controlling partners	$	6.0	$	(256.0	)	$	11.9	$	(246.2	)

Crestwood Midstream Partners LP

Distribution Made to Limited Partner [Line Items]

Schedule of Distributions Made to Members or Limited Partners, by Distribution

The following table presents quarterly cash distributions paid to Crestwood Midstream's limited partners (excluding distributions paid to its general partner on its common units held) during the six months endedJune 30, 2015.

Record Date	Payment Date	Per Unit Rate		Cash Distributions (in millions)
February 6, 2015	February 13, 2015	$	0.41	$	74.3
May 8, 2015	May 15, 2015	0.41		74.3
				$	148.6

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Related Party Transactions (Tables)

6 Months Ended

Jun. 30, 2016

Related Party Transactions [Abstract]

Schedule of Related Party Transactions

The following table shows revenues, costs of product/services sold, general and administrative expenses and reimbursements of expenses from our affiliates for the three and six months endedJune 30, 2016 and 2015 (in millions):

	Three Months Ended					Six Months Ended
	June 30,					June 30,
	2016			2015		2016			2015
Gathering and processing revenues at CEQP and CMLP	$	0.7		$	1.1	$	1.4		$	2.1
Gathering and processing costs of product/services sold at CEQP and CMLP(1)	$	4.4		$	7.7	$	8.7		$	16.0
Operations and maintenance expenses charged by CEQP and CMLP	$	1.0		$	0.7	$	1.7		$	1.6
General and administrative expenses charged by CEQP to CMLP, net(2)	$	3.2		$	14.4	$	6.9		$	31.8
General and administrative expenses charged by (from) CEQP to Crestwood Holdings, net(3)	$	(0.2	)	$	0.1	$	(0.1	)	$	0.2

(1) Represents natural gas purchases from Sabine Oil and Gas Corporation.

(2) Includes $3.9 million and $8.4 million of net unit-based compensation charges allocated from CEQP to CMLP for the three and six months endedJune 30, 2016 and $2.2 million and $4.4 million for the three and six months endedJune 30, 2015. In addition, prior to the completion of the Simplification Merger, CEQP allocated general and administrative costs to CMLP. In conjunction with the Simplification Merger, CMLP shares common management, general and administrative and overhead costs with CEQP. During the three and six months endedJune 30, 2016, CMLP allocated $0.7 million and $1.5 million of general and administrative costs to CEQP.

(3) Includes $0.9 million unit-based compensation charges allocated from Crestwood Holdings to CEQP and CMLP during the three and six months ended2016.

Schedule of Related Party Receivables and Payables

The following table shows accounts receivable and accounts payable from our affiliates as of June 30, 2016 and December 31, 2015 (in millions):

	CEQP				CMLP
	June 30, 2016		December 31, 2015		June 30, 2016		December 31, 2015
Accounts receivable	$	2.1	$	1.7	$	2.1	$	1.7
Accounts payable	$	6.3	$	4.0	$	3.8	$	1.5

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Segments (Tables)

6 Months Ended

Jun. 30, 2016

Segment Reporting, Other Significant Reconciling Item [Line Items]

Reconciliation of Net Income (Loss) to Earnings Before Interest, Taxes, Depreciation and Amortization

Below is a reconciliation of CEQP's net loss to EBITDA (in millions):

	Three Months Ended						Six Months Ended
	June 30,						June 30,
	2016			2015			2016			2015
Net loss	$	(37.1	)	$	(296.0	)	$	(130.8	)	$	(277.9	)
Add:
Interest and debt expense, net	34.3			35.4			70.4			69.0
(Gain) loss on modification/extinguishment of debt	(10.0		)	17.1			(10.0		)	17.1
Provision (benefit) for income taxes	—			(0.3		)	—			0.1
Depreciation, amortization and accretion	64.4			74.8			126.7			149.0
EBITDA	$	51.6		$	(169.0	)	$	56.3		$	(42.7	)

Summary Of Segment Information

	Three Months Ended June 30, 2016
	Gathering and Processing		Storage and Transportation			Marketing, Supply and Logistics			Corporate			Total
Revenues	$	269.5	$	53.8		$	278.6		$	—		$	601.9
Intersegment revenues	30.6		1.1			(31.7		)	—			—
Costs of product/services sold	226.3		1.9			221.8			—			450.0
Operations and maintenance expense	20.9		8.5			15.6			—			45.0
General and administrative expense	—		—			—			28.9			28.9
Loss on long-lived assets	—		(32.7		)	—			—			(32.7		)
Earnings from unconsolidated affiliates, net	5.9		0.3			—			—			6.2
Other income, net	—		—			—			0.1			0.1
EBITDA	$	58.8	$	12.1		$	9.5		$	(28.8	)	$	51.6
Goodwill	$	45.9	$	31.2		$	172.4		$	—		$	249.5
Total assets	$	2,394.1	$	1,191.2		$	974.8		$	33.3		$	4,593.4
Purchases of property, plant and equipment	$	4.2	$	11.6		$	4.7		$	0.1		$	20.6

	Three Months Ended June 30, 2015
	Gathering and Processing			Storage and Transportation		Marketing, Supply and Logistics			Corporate			Total
Revenues	$	346.8		$	68.5	$	226.2		$	—		$	641.5
Intersegment revenues	33.8			—		(33.8		)	—			—
Costs of product/services sold	293.1			5.3		161.1			—			459.5
Operations and maintenance expense	22.3			5.9		15.7			—			43.9
General and administrative expense	—			—		—			30.6			30.6
Loss on long-lived assets	(0.6		)	—		—			—			(0.6		)
Goodwill impairment	(220.7		)	—		(60.3		)	—			(281.0		)
Earnings from unconsolidated affiliates, net	1.1			3.9		—			—			5.0
Other income, net	—			—		—			0.1			0.1
EBITDA	$	(155.0	)	$	61.2	$	(44.7	)	$	(30.5	)	$	(169.0	)
Purchases of property, plant and equipment	$	28.4		$	3.9	$	3.6		$	0.2		$	36.1

	Six Months Ended June 30, 2016
	Gathering and Processing			Storage and Transportation			Marketing, Supply and Logistics			Corporate			Total
Revenues	$	508.4		$	113.2		$	516.3		$	—		$	1,137.9
Intersegment revenues	51.1			1.5			(52.6		)	—			—
Costs of product/services sold	406.1			4.8			402.5			—			813.4
Operations and maintenance expense	38.7			15.7			32.4			—			86.8
General and administrative expense	—			—			—			51.9			51.9
Loss on long-lived assets	—			(32.7		)	—			—			(32.7		)
Goodwill impairment	(8.6		)	(13.7		)	(87.4		)	—			(109.7		)
Earnings from unconsolidated affiliates, net	11.0			1.7			—			—			12.7
Other income, net	—			—			—			0.2			0.2
EBITDA	$	117.1		$	49.5		$	(58.6	)	$	(51.7	)	$	56.3
Goodwill	$	45.9		$	31.2		$	172.4		$	—		$	249.5
Total assets	$	2,394.1		$	1,191.2		$	974.8		$	33.3		$	4,593.4
Purchases of property, plant and equipment	$	48.5		$	14.9		$	11.8		$	1.0		$	76.2

	Six Months Ended June 30, 2015
	Gathering and Processing			Storage and Transportation			Marketing, Supply and Logistics			Corporate			Total
Revenues	$	697.1		$	136.1		$	539.8		$	—		$	1,373.0
Intersegment revenues	43.9			—			(43.9		)	—			—
Costs of product/services sold	559.8			10.6			418.8			—			989.2
Operations and maintenance expense	46.4			12.3			35.8			—			94.5
General and administrative expense	—			—			—			58.1			58.1
Goodwill impairment	(220.7		)	—			(60.3		)	—			(281.0		)
Loss on long-lived assets	(0.9		)	(0.7		)	—			—			(1.6		)
Earnings from unconsolidated affiliates, net	3.6			4.8			—			—			8.4
Other income, net	—			—			—			0.3			0.3
EBITDA	$	(83.2	)	$	117.3		$	(19.0	)	$	(57.8	)	$	(42.7	)
Purchases of property, plant and equipment	$	64.6		$	8.0		$	10.5		$	0.4		$	83.5

Crestwood Midstream Partners LP

Segment Reporting, Other Significant Reconciling Item [Line Items]

Reconciliation of Net Income (Loss) to Earnings Before Interest, Taxes, Depreciation and Amortization

Below is a reconciliation of CMLP's net loss to EBITDA (in millions):

	Three Months Ended						Six Months Ended
	June 30,						June 30,
	2016			2015			2016			2015
Net loss	$	(35.6	)	$	(72.8	)	$	(130.9	)	$	(43.7	)
Add:
Interest and debt expense, net	34.3			32.6			70.4			62.5
(Gain) loss on modification/extinguishment of debt	(10.0		)	17.1			(10.0		)	17.1
Provision for income taxes	0.2			0.1			—			0.5
Depreciation, amortization and accretion	67.1			69.5			132.0			138.3
EBITDA	$	56.0		$	46.5		$	61.5		$	174.7

Summary Of Segment Information

	Three Months Ended June 30, 2016
	Gathering and Processing		Storage and Transportation			Marketing, Supply and Logistics			Corporate			Total
Revenues	$	269.5	$	53.8		$	278.6		$	—		$	601.9
Intersegment revenues	30.6		1.1			(31.7		)	—			—
Costs of product/services sold	226.3		1.9			221.8			—			450.0
Operations and maintenance expense	20.9		4.9			15.6			—			41.4
General and administrative expense	—		—			—			28.0			28.0
Loss on long-lived assets	—		(32.7		)	—			—			(32.7		)
Earnings from unconsolidated affiliates, net	5.9		0.3			—			—			6.2
EBITDA	$	58.8	$	15.7		$	9.5		$	(28.0	)	$	56.0
Goodwill	$	45.9	$	31.2		$	172.4		$	—		$	249.5
Total assets	$	2,603.3	$	1,188.9		$	974.8		$	18.9		$	4,785.9
Purchases of property, plant and equipment	$	4.2	$	11.6		$	4.7		$	0.1		$	20.6

	Three Months Ended June 30, 2015
	Gathering and Processing			Storage and Transportation			Marketing, Supply and Logistics			Corporate			Total
Revenues	$	346.8		$	68.5		$	226.2		$	—		$	641.5
Intersegment revenues	33.8			—			(33.8		)	—			—
Costs of product/services sold	293.1			5.3			161.1			—			459.5
Operations and maintenance expense	22.3			5.9			15.7			—			43.9
General and administrative expense	—			—			—			27.3			27.3
Goodwill impairment	(8.3		)	—			(60.3		)	—			(68.6		)
Loss on long-lived assets	(0.6		)	(0.1		)	—			—			(0.7		)
Earnings from unconsolidated affiliates, net	1.1			3.9			—			—			5.0
EBITDA	$	57.4		$	61.1		$	(44.7	)	$	(27.3	)	$	46.5
Purchases of property, plant and equipment	$	28.4		$	3.9		$	3.6		$	0.2		$	36.1

	Six Months Ended June 30, 2016
	Gathering and Processing			Storage and Transportation			Marketing, Supply and Logistics			Corporate			Total
Revenues	$	508.4		$	113.2		$	516.3		$	—		$	1,137.9
Intersegment revenues	51.1			1.5			(52.6		)	—			—
Costs of product/services sold	406.1			4.8			402.5			—			813.4
Operations and maintenance expense	38.7			12.0			32.4			—			83.1
General and administrative expense	—			—			—			50.2			50.2
Goodwill impairment	(8.6		)	(13.7		)	(87.4		)	—			(109.7		)
Loss on long-lived assets	—			(32.7		)	—			—			(32.7		)
Earnings from unconsolidated affiliates, net	11.0			1.7			—			—			12.7
EBITDA	$	117.1		$	53.2		$	(58.6	)	$	(50.2	)	$	61.5
Goodwill	$	45.9		$	31.2		$	172.4		$	—		$	249.5
Total assets	$	2,603.3		$	1,188.9		$	974.8		$	18.9		$	4,785.9
Purchases of property, plant and equipment	$	48.5		$	14.9		$	11.8		$	1.0		$	76.2

	Six Months Ended June 30, 2015
	Gathering and Processing			Storage and Transportation			Marketing, Supply and Logistics			Corporate			Total
Revenues	$	697.1		$	136.1		$	539.8		$	—		$	1,373.0
Intersegment revenues	43.9			—			(43.9		)	—			—
Costs of product/services sold	559.8			10.6			418.8			—			989.2
Operations and maintenance expense	46.4			12.3			35.8			—			94.5
General and administrative expense	—			—			—			52.9			52.9
Goodwill impairment	(8.3		)	—			(60.3		)	—			(68.6		)
Loss on long-lived assets	(0.9		)	(0.6		)	—			—			(1.5		)
Earnings from unconsolidated affiliates, net	3.6			4.8			—			—			8.4
EBITDA	$	129.2		$	117.4		$	(19.0	)	$	(52.9	)	$	174.7
Purchases of property, plant and equipment	$	64.6		$	8.0		$	10.5		$	0.4		$	83.5

XML

Condensed Consolidating Financial Information (Tables)

6 Months Ended

Jun. 30, 2016

Condensed Financial Information of Parent Company Only Disclosure [Abstract]

Condensed Balance Sheet

Crestwood Midstream Partners LP
Condensed Consolidating Balance Sheet
June 30, 2016
(in millions)
	Parent		Guarantor Subsidiaries		Non- Guarantor Subsidiaries		Eliminations			Consolidated
Assets
Current assets:
Cash	$	0.2	$	—	$	—	$	—		$	0.2
Accounts receivable	—		242.4		1.9		—			244.3
Inventory	—		43.5		—		—			43.5
Assets held for sale	—		55.0		—		—			55.0
Other current assets	—		19.8		—		—			19.8
Total current assets	0.2		360.7		1.9		—			362.8
Property, plant and equipment, net	—		2,355.9		—		—			2,355.9
Goodwill and intangible assets, net	—		965.2		—		—			965.2
Investment in consolidated affiliates	4,310.1		—		—		(4,310.1		)	—
Investment in unconsolidated affiliates	—		—		1,099.1		—			1,099.1
Other assets	—		2.9		—		—			2.9
Total assets	$	4,310.3	$	3,684.7	$	1,101.0	$	(4,310.1	)	$	4,785.9
Liabilities and partners' capital
Current liabilities:
Accounts payable	$	—	$	161.8	$	—	$	—		$	161.8
Other current liabilities	23.4		82.9		—		—			106.3
Total current liabilities	23.4		244.7		—		—			268.1
Long-term liabilities:
Long-term debt, less current portion	1,580.1		1.5		—		—			1,581.6
Other long-term liabilities	—		40.9		—		—			40.9
Deferred income taxes	—		0.7		—		—			0.7
Partners' capital	2,706.8		3,396.9		913.2		(4,310.1		)	2,706.8
Interest of non-controlling partners in subsidiaries	—		—		187.8		—			187.8
Total partners' capital	2,706.8		3,396.9		1,101.0		(4,310.1		)	2,894.6
Total liabilities and partners' capital	$	4,310.3	$	3,684.7	$	1,101.0	$	(4,310.1	)	$	4,785.9

Crestwood Midstream Partners LP
Condensed Consolidating Balance Sheet
December 31, 2015
(in millions)
	Parent		Guarantor Subsidiaries		Non- Guarantor Subsidiaries		Eliminations			Consolidated
Assets
Current assets:
Cash	$	0.1	$	—	$	—	$	—		$	0.1
Accounts receivable	—		236.0		0.5		—			236.5
Inventory	—		44.5		—		—			44.5
Other current assets	—		52.5		—		—			52.5
Total current assets	0.1		333.0		0.5		—			333.6
Property, plant and equipment, net	—		3,525.7		—		—			3,525.7
Goodwill and intangible assets, net	—		1,846.9		—		—			1,846.9
Investment in consolidated affiliates	5,506.8		—		—		(5,506.8		)	—
Investment in unconsolidated affiliates	—		—		254.3		—			254.3
Other assets	—		3.1		—		—			3.1
Total assets	$	5,506.9	$	5,708.7	$	254.8	$	(5,506.8	)	$	5,963.6
Liabilities and partners' capital
Current liabilities:
Accounts payable	$	—	$	141.3	$	0.1	$	—		$	141.4
Other current liabilities	26.4		85.2		—		—			111.6
Total current liabilities	26.4		226.5		0.1		—			253.0
Long-term liabilities:
Long-term debt, less current portion	2,498.9		2.9		—		—			2,501.8
Other long-term liabilities	—		43.3		—		—			43.3
Deferred income taxes	—		0.4		—		—			0.4
Partners' capital	2,981.6		5,435.6		71.2		(5,506.8		)	2,981.6
Interest of non-controlling partners in subsidiaries	—		—		183.5		—			183.5
Total partners' capital	2,981.6		5,435.6		254.7		(5,506.8		)	3,165.1
Total liabilities and partners' capital	$	5,506.9	$	5,708.7	$	254.8	$	(5,506.8	)	$	5,963.6

Condensed Income Statement

Crestwood Midstream Partners LP
Condensed Consolidating Statement of Operations
Six Months Ended June 30, 2015
(in millions)
	Parent			Guarantor Subsidiaries			Non- Guarantor Subsidiaries			Eliminations			Consolidated
Revenues	$	—		$	1,373.0		$	—		$	—		$	1,373.0
Costs of product/services sold	—			989.2			—			—			989.2
Expenses:
Operations and maintenance	—			94.5			—			—			94.5
General and administrative	29.8			23.1			—			—			52.9
Depreciation, amortization and accretion	1.1			137.2			—			—			138.3
	30.9			254.8			—			—			285.7
Other operating expense:
Loss on long-lived assets, net	—			(1.5		)	—			—			(1.5		)
Goodwill Impairment	—			(68.6		)	—			—			(68.6		)
Operating income (loss)	(30.9		)	58.9			—			—			28.0
Earnings from unconsolidated affiliates, net	—			—			8.4			—			8.4
Interest and debt expense, net	(62.5		)	—			—			—			(62.5		)
Loss on modification/extinguishment of debt	(17.1		)	—			—			—			(17.1		)
Equity in net income (loss) of subsidiary	66.8			—			—			(66.8		)	—
Income (loss) before income taxes	(43.7		)	58.9			8.4			(66.8		)	(43.2		)
Provision for income taxes	—			0.5			—			—			0.5
Net income (loss)	(43.7		)	58.4			8.4			(66.8		)	(43.7		)
Net income attributable to non-controlling partners in subsidiaries	—			—			11.3			—			11.3
Net income (loss) attributable to Crestwood Midstream Partners LP	(43.7		)	58.4			(2.9		)	(66.8		)	(55.0		)
Net income attributable to Class A preferred units	16.7			—			—			—			16.7
Net income (loss) attributable to partners	$	(60.4	)	$	58.4		$	(2.9	)	$	(66.8	)	$	(71.7	)

Crestwood Midstream Partners LP
Condensed Consolidating Statement of Operations
Three Months Ended June 30, 2016
(in millions)
	Parent			Guarantor Subsidiaries			Non- Guarantor Subsidiaries		Eliminations			Consolidated
Revenues	$	—		$	601.9		$	—	$	—		$	601.9
Costs of product/services sold	—			450.0			—		—			450.0
Expenses:
Operations and maintenance	—			41.4			—		—			41.4
General and administrative	23.2			4.8			—		—			28.0
Depreciation, amortization and accretion	—			67.1			—		—			67.1
	23.2			113.3			—		—			136.5
Other operating expense:
Loss on long-lived assets, net	—			(32.7		)	—		—			(32.7		)
Goodwill impairment	—			—			—		—			—
Operating income (loss)	(23.2		)	5.9			—		—			(17.3		)
Earnings from unconsolidated affiliates, net	—			—			6.2		—			6.2
Interest and debt expense, net	(34.3		)	—			—		—			(34.3		)
Gain on modification/extinguishment of debt	10.0			—			—		—			10.0
Equity in net income (loss) of subsidiary	11.9			—			—		(11.9		)	—
Income (loss) before income taxes	(35.6		)	5.9			6.2		(11.9		)	(35.4		)
Provision for income taxes	—			0.2			—		—			0.2
Net income (loss)	(35.6		)	5.7			6.2		(11.9		)	(35.6		)
Net income attributable to non-controlling partners in subsidiaries	—			—			6.0		—			6.0
Net income (loss) attributable to Crestwood Midstream Partners LP	$	(35.6	)	$	5.7		$	0.2	$	(11.9	)	$	(41.6	)

Crestwood Midstream Partners LP
Condensed Consolidating Statement of Operations
Three Months Ended June 30, 2015
(in millions)
	Parent			Guarantor Subsidiaries			Non- Guarantor Subsidiaries			Eliminations		Consolidated
Revenues	$	—		$	641.5		$	—		$	—	$	641.5
Costs of product/services sold	—			459.5			—			—		459.5
Expenses:
Operations and maintenance	—			43.9			—			—		43.9
General and administrative	16.4			10.9			—			—		27.3
Depreciation, amortization and accretion	0.9			68.6			—			—		69.5
	17.3			123.4			—			—		140.7
Other operating expense:
Loss on long-lived assets, net	—			(0.7		)	—			—		(0.7		)
Goodwill Impairment	—			(68.6		)	—			—		(68.6		)
Operating loss	(17.3		)	(10.7		)	—			—		(28.0		)
Earnings from unconsolidated affiliates, net	—			—			5.0			—		5.0
Interest and debt expense, net	(32.6		)	—			—			—		(32.6		)
Loss on modification/extinguishment of debt	(17.1		)	—			—			—		(17.1		)
Equity in net income (loss) of subsidiary	(5.8		)	—			—			5.8		—
Income (loss) before income taxes	(72.8		)	(10.7		)	5.0			5.8		(72.7		)
Provision for income taxes	—			0.1			—			—		0.1
Net income (loss)	(72.8		)	(10.8		)	5.0			5.8		(72.8		)
Net income attributable to non-controlling partners in subsidiaries	—			—			5.7			—		5.7
Net income (loss) attributable to Crestwood Midstream Partners LP	(72.8		)	(10.8		)	(0.7		)	5.8		(78.5		)
Net income attributable to Class A preferred units	7.5			—			—			—		7.5
Net income (loss) attributable to partners	$	(80.3	)	$	(10.8	)	$	(0.7	)	$	5.8	$	(86.0	)

Crestwood Midstream Partners LP
Condensed Consolidating Statement of Operations
Six Months Ended June 30, 2016
(in millions)
	Parent			Guarantor Subsidiaries			Non- Guarantor Subsidiaries		Eliminations		Consolidated
Revenues	$	—		$	1,137.9		$	—	$	—	$	1,137.9
Costs of product/services sold	—			813.4			—		—		813.4
Expenses:
Operations and maintenance	—			83.1			—		—		83.1
General and administrative	40.9			9.3			—		—		50.2
Depreciation, amortization and accretion	—			132.0			—		—		132.0
	40.9			224.4			—		—		265.3
Other operating expense:
Loss on long-lived assets, net	—			(32.7		)	—		—		(32.7		)
Goodwill impairment	—			(109.7		)	—		—		(109.7		)
Operating loss	(40.9		)	(42.3		)	—		—		(83.2		)
Earnings from unconsolidated affiliates, net	—			—			12.7		—		12.7
Interest and debt expense, net	(70.4		)	—			—		—		(70.4		)
Gain on modification/extinguishment of debt	10.0			—			—		—		10.0
Equity in net income (loss) of subsidiary	(29.6		)	—			—		29.6		—
Net income (loss)	(130.9		)	(42.3		)	12.7		29.6		(130.9		)
Net income attributable to non-controlling partners in subsidiaries	—			—			11.9		—		11.9
Net income (loss) attributable to Crestwood Midstream Partners LP	$	(130.9	)	$	(42.3	)	$	0.8	$	29.6	$	(142.8	)

Condensed Cash Flow Statement

Crestwood Midstream Partners LP
Condensed Consolidating Statement of Cash Flows
Six Months Ended June 30, 2016
(in millions)
	Parent			Guarantor Subsidiaries			Non- Guarantor Subsidiaries			Eliminations			Consolidated
Cash flows from operating activities:	$	(110.9	)	$	296.5		$	10.4		$	—		$	196.0
Cash flows from investing activities:
Purchases of property, plant and equipment	(1.0		)	(75.2		)	—			—			(76.2		)
Investment in unconsolidated affiliates	—			—			(5.5		)	—			(5.5		)
Proceeds from the sale of assets	—			942.0			—			—			942.0
Capital distributions from unconsolidated affiliates	—			—			5.5			—			5.5
Capital distributions from consolidated affiliates	2.8			—			—			(2.8		)	—
Net cash provided by (used in) investing activities	1.8			866.8			—			(2.8		)	865.8
Cash flows from financing activities:
Proceeds from the issuance of long-term debt	1,078.8			—			—			—			1,078.8
Principal payments on long-term debt	(1,986.8		)	(0.7		)	—			—			(1,987.5		)
Payments on capital leases	—			(0.9		)	—			—			(0.9		)
Payments for debt-related deferred costs	(3.3		)	—			—			—			(3.3		)
Distributions paid	(140.6		)	—			(7.6		)	—			(148.2		)
Distributions to parent	—			—			(2.8		)	2.8			—
Taxes paid for unit-based compensation vesting	—			(0.6		)	—			—			(0.6		)
Change in intercompany balances	1,161.1			(1,161.1		)	—			—			—
Net cash provided by (used in) financing activities	109.2			(1,163.3		)	(10.4		)	2.8			(1,061.7		)
Net change in cash	0.1			—			—			—			0.1
Cash at beginning of period	0.1			—			—			—			0.1
Cash at end of period	$	0.2		$	—		$	—		$	—		$	0.2

Crestwood Midstream Partners LP
Condensed Consolidating Statement of Cash Flows
Six Months Ended June 30, 2015
(in millions)
	Parent			Guarantor Subsidiaries			Non- Guarantor Subsidiaries			Eliminations			Consolidated
Cash flows from operating activities:	$	(89.1	)	$	286.6		$	6.0		$	—		$	203.5
Cash flows from investing activities:
Purchases of property, plant and equipment	(0.4		)	(83.1		)	—			—			(83.5		)
Investment in unconsolidated affiliates	—			—			(27.8		)	—			(27.8		)
Capital distributions from unconsolidated affiliates	—			—			1.0			—			1.0
Proceeds from the sale of assets	—			2.1			—			—			2.1
Capital contributions to consolidated affiliates	(24.6		)	—			—			24.6			—
Net cash provided by (used in) investing activities	(25.0		)	(81.0		)	(26.8		)	24.6			(108.2		)
Cash flows from financing activities:
Proceeds from the issuance of long-term debt	1,865.1			—			—			—			1,865.1
Principal payments on long-term debt	(1,713.2		)	—			—			—			(1,713.2		)
Payments on capital leases	(0.9		)	(0.3		)	—			—			(1.2		)
Payments for debt-related deferred costs	(11.7		)	—			—			—			(11.7		)
Financing fees paid for early debt redemption	(13.6		)	—			—			—			(13.6		)
Distributions paid	(221.4		)	—			(3.8		)	—			(225.2		)
Contributions from parent	—			—			24.6			(24.6		)	—
Taxes paid for unit-based compensation vesting	—			(2.1		)	—			—			(2.1		)
Change in intercompany balances	210.0			(210.0		)	—			—			—
Other	(0.2		)	—			—			—			(0.2		)
Net cash provided by (used in) financing activities	114.1			(212.4		)	20.8			(24.6		)	(102.1		)
Net change in cash	—			(6.8		)	—			—			(6.8		)
Cash at beginning of period	—			7.6			—			—			7.6
Cash at end of period	$	—		$	0.8		$	—		$	—		$	0.8

XML

Organization and Business Description (Narrative) (Detail)	6 Months Ended
	Jun. 30, 2016 segment
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Number of Operating Segments	3

XML

Basis of Presentation and Summary of Significant Accounting Policies (Details) $ in Millions	1 Months Ended	3 Months Ended		6 Months Ended		12 Months Ended
	Apr. 30, 2016 USD ($)	Jun. 30, 2016 USD ($)	Jun. 30, 2015 USD ($)	Jun. 30, 2016 USD ($)	Jun. 30, 2015 USD ($)	Dec. 31, 2015 USD ($)
Summary Of Significant Accounting Policies [Line Items]
Miles of Pipeline		37.5		37.5
Net proceeds from sale of assets	$ 945.0			$ 942.0	$ 2.1
Property Plant and Equipment Disposition				1,094.6
Increase (Decrease) in Intangible Assets, Current				8.5
Increase (Decrease) in Other Current Assets and Liabilities, Net				$ 10.9
Impaired Assets to be Disposed of by Method Other than Sale, Amount of Impairment Loss						$ 354.4
Percentage Disposition Exceeded Carrying Value Of Property Plant And Equipment		30.00%		30.00%		0.00%
Deferred Finance Costs, Net		$ 37.6		$ 37.6		$ 40.9
Goodwill [Roll Forward]
Goodwill at				1,085.5
Goodwill impairment		0.0	$ 281.0	109.7	$ 281.0
Goodwill at		249.5		249.5		1,085.5
Goodwill, Written off Related to Sale of Business Unit				726.3
Fayetteville
Goodwill [Roll Forward]
Goodwill impairment			8.3
Marcellus
Goodwill [Roll Forward]
Goodwill at				8.6
Goodwill impairment		8.6
Goodwill at		0.0		0.0		8.6
Arrow
Goodwill [Roll Forward]
Goodwill at				45.9
Goodwill impairment		0.0
Goodwill at		45.9		45.9		45.9
Northeast Storage and Transportation
Goodwill [Roll Forward]
Goodwill at				726.3
Goodwill impairment		0.0
Goodwill at		0.0		0.0		726.3
Goodwill, Written off Related to Sale of Business Unit				726.3
COLT
Goodwill [Roll Forward]
Goodwill at				44.9
Goodwill impairment		13.7
Goodwill at		31.2		31.2		44.9
Supply and Logistics
Goodwill [Roll Forward]
Goodwill at				167.2
Goodwill impairment		65.5
Goodwill at		101.7		101.7		167.2
Storage and Terminals
Goodwill [Roll Forward]
Goodwill at				50.5
Goodwill impairment		14.1
Goodwill at		36.4		36.4		50.5
US Salt
Goodwill [Roll Forward]
Goodwill at				12.6
Goodwill impairment		0.0
Goodwill at		12.6		12.6		12.6
Trucking
Goodwill [Roll Forward]
Goodwill at				29.5
Goodwill impairment		7.8
Goodwill at		$ 21.7		$ 21.7		$ 29.5
West Coast
Goodwill [Roll Forward]
Goodwill impairment			28.4
Watkins Glen
Goodwill [Roll Forward]
Goodwill impairment			31.9
Barnett
Goodwill [Roll Forward]
Goodwill impairment			$ 212.4
Minimum
Summary Of Significant Accounting Policies [Line Items]
Fair Value Inputs, Discount Rate				10.00%
Minimum | Watkins Glen
Summary Of Significant Accounting Policies [Line Items]
Fair Value Inputs, Discount Rate					10.50%
Minimum | Fayetteville and West Coast
Summary Of Significant Accounting Policies [Line Items]
Fair Value Inputs, Discount Rate					9.00%
Minimum | Barnett
Summary Of Significant Accounting Policies [Line Items]
Fair Value Inputs, Discount Rate					9.00%
Maximum
Summary Of Significant Accounting Policies [Line Items]
Fair Value Inputs, Discount Rate				19.00%
Maximum | Watkins Glen
Summary Of Significant Accounting Policies [Line Items]
Fair Value Inputs, Discount Rate					13.30%
Maximum | Fayetteville and West Coast
Summary Of Significant Accounting Policies [Line Items]
Fair Value Inputs, Discount Rate					10.00%
Maximum | Barnett
Summary Of Significant Accounting Policies [Line Items]
Fair Value Inputs, Discount Rate					11.00%
CEGP
Summary Of Significant Accounting Policies [Line Items]
Net proceeds from sale of assets				$ 30.0
Ownership Percentage	50.00%	50.00%		50.00%

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Certain Balance Sheet Information (Accrued Expenses and Other Liabilities) (Details) - USD ($) $ in Millions	1 Months Ended	6 Months Ended
	Apr. 30, 2016	Jun. 30, 2016	Jun. 30, 2015	Dec. 31, 2015
Accrued Expenses and Other Liabilities [Line Items]
Net proceeds from sale of assets	$ 945.0	$ 942.0	$ 2.1
Payments to acquire equity method investments		5.5	28.0
Accrued expenses		35.5		$ 46.4
Accrued property taxes		12.3		4.8
Accrued product purchases payable		2.8		1.5
Tax payable		0.6		0.5
Interest payable		23.2		26.2
Accrued additions to property, plant and equipment		2.9		10.4
Capital leases		1.3		1.6
Deferred revenue		22.6		14.2
Total accrued expenses and other liabilities		101.2		105.6
CEGP
Accrued Expenses and Other Liabilities [Line Items]
Net proceeds from sale of assets		30.0
Crestwood Midstream Partners LP
Accrued Expenses and Other Liabilities [Line Items]
Net proceeds from sale of assets		942.0	2.1
Payments to acquire equity method investments		5.5	$ 27.8
Accrued expenses		33.8		44.1
Accrued property taxes		7.3		4.8
Accrued product purchases payable		2.8		1.5
Tax payable		0.6		0.5
Interest payable		23.2		26.2
Accrued additions to property, plant and equipment		2.9		10.4
Capital leases		1.3		1.6
Deferred revenue		22.6		14.2
Total accrued expenses and other liabilities		$ 94.5		$ 103.3

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Investments in Unconsolidated Affiliates (Net Investments In and Earnings (Loss) from Unconsolidated Affiliates) (Details) - USD ($) $ in Millions	1 Months Ended	3 Months Ended		6 Months Ended
	Apr. 30, 2016	Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015	Jun. 03, 2016	Dec. 31, 2015
Schedule of Equity Method Investments [Line Items]
Net proceeds from sale of assets	$ 945.0			$ 942.0	$ 2.1
Investment		$ 1,099.1		1,099.1			$ 254.3
Earnings from unconsolidated affiliates, net		6.2	$ 5.0	12.7	8.4
Goodwill		$ 249.5		249.5			1,085.5
Stagecoach Gas Services LLC
Schedule of Equity Method Investments [Line Items]
Net proceeds from sale of assets				$ 3.0
Ownership Percentage		50.00%		50.00%
Investment		$ 846.3		$ 846.3		$ 844.0	0.0
Earnings from unconsolidated affiliates, net		2.3	0.0	2.3	0.0
Difference between carrying amount and underlying equity		$ 50.8		50.8
Jackalope Gas Gathering Services, L.L.C.
Schedule of Equity Method Investments [Line Items]
Proceeds from equity method investments				$ 12.1	4.5
Ownership Percentage		50.00%		50.00%
Investment		$ 201.3		$ 201.3			202.4
Earnings from unconsolidated affiliates, net		5.9	1.1	11.0	3.6
Difference between carrying amount and underlying equity		$ 0.8		0.8
Amortization			0.7	0.1	1.5
Tres Palacios Holdings LLC
Schedule of Equity Method Investments [Line Items]
Proceeds from equity method investments				$ 4.1	2.1
Ownership Percentage		50.01%		50.01%
Investment		$ 36.7		$ 36.7			36.8
Earnings from unconsolidated affiliates, net		(2.3)	0.6	(1.5)	1.5
Difference between carrying amount and underlying equity		28.5		28.5
Amortization		$ 0.3		0.6	0.6
Powder River Basin Industrial Complex, LLC
Schedule of Equity Method Investments [Line Items]
Proceeds from equity method investments				$ 1.2	0.7
Ownership Percentage		50.01%		50.01%
Investment		$ 14.8		$ 14.8			$ 15.1
Earnings from unconsolidated affiliates, net		0.3	$ 3.3	0.9	3.3
Difference between carrying amount and underlying equity		22.6		22.6
Goodwill		10.6		10.6
Amortization		$ 0.4		$ 0.8
Income (loss) from Equity Method Investments, Capital Adjustment					$ 3.2

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Investments in Unconsolidated Affiliates Narrative (Details) - USD ($) $ in Millions	1 Months Ended		3 Months Ended		6 Months Ended
	Jul. 31, 2016	Apr. 30, 2016	Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015	Jun. 03, 2016	Dec. 31, 2015
Schedule of Equity Method Investments [Line Items]
Net proceeds from sale of assets		$ 945.0			$ 942.0	$ 2.1
Investment in unconsolidated affiliates (Note 4)			$ 1,099.1		1,099.1			$ 254.3
Payments to acquire equity method investments					5.5	28.0
Deconsolidation, Gain (Loss), Amount					$ 32.9
Jackalope Gas Gathering Services, L.L.C.
Schedule of Equity Method Investments [Line Items]
Ownership Percentage			50.00%		50.00%
Investment in unconsolidated affiliates (Note 4)			$ 201.3		$ 201.3			202.4
Proceeds from equity method investments					12.1	4.5
Amortization				$ 0.7	$ 0.1	1.5
Tres Palacios Holdings LLC
Schedule of Equity Method Investments [Line Items]
Ownership Percentage			50.01%		50.01%
Investment in unconsolidated affiliates (Note 4)			$ 36.7		$ 36.7			36.8
Proceeds from equity method investments					4.1	2.1
Payments to acquire equity method investments					5.5	5.7
Amortization			$ 0.3		$ 0.6	0.6
Powder River Basin Industrial Complex, LLC
Schedule of Equity Method Investments [Line Items]
Ownership Percentage			50.01%		50.01%
Investment in unconsolidated affiliates (Note 4)			$ 14.8		$ 14.8			15.1
Proceeds from equity method investments					1.2	0.7
Payments to acquire equity method investments						4.2
Amortization			$ 0.4		$ 0.8
Stagecoach Gas Services LLC
Schedule of Equity Method Investments [Line Items]
Ownership Percentage			50.00%		50.00%
Net proceeds from sale of assets					$ 3.0
Investment in unconsolidated affiliates (Note 4)			$ 846.3		846.3		$ 844.0	0.0
Crestwood Equity Partners LP
Schedule of Equity Method Investments [Line Items]
Interest, Taxes, Depreciation and Amortization included in Earnings from Equity Method Investments			4.4	0.7	7.0	3.8
Crestwood Niobrara LLC | Jackalope Gas Gathering Services, L.L.C.
Schedule of Equity Method Investments [Line Items]
Payments to acquire equity method investments						17.9
Crestwood Midstream Partners LP
Schedule of Equity Method Investments [Line Items]
Net proceeds from sale of assets					942.0	2.1
Investment in unconsolidated affiliates (Note 4)			1,099.1		1,099.1			$ 254.3
Interest, Taxes, Depreciation and Amortization included in Earnings from Equity Method Investments			$ 4.4	$ 0.7	7.0	3.8
Payments to acquire equity method investments					$ 5.5	$ 27.8
Subsequent Event | Tres Palacios Holdings LLC
Schedule of Equity Method Investments [Line Items]
Proceeds from equity method investments	$ 2.1
Subsequent Event | Powder River Basin Industrial Complex, LLC
Schedule of Equity Method Investments [Line Items]
Proceeds from equity method investments	0.4
Subsequent Event | Stagecoach Gas Services LLC
Schedule of Equity Method Investments [Line Items]
Proceeds from equity method investments	$ 3.7

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Risk Management (Notional Amounts and Terms of Company's Derivative Financial Instruments) (Details) - Propane Crude And Heating Oil - bbl bbl in Millions	Jun. 30, 2016	Dec. 31, 2015
Fixed Price Payor
Derivative [Line Items]
Derivative, notional amount	12.4	9.1
Fixed Price Receiver
Derivative [Line Items]
Derivative, notional amount	13.8	10.9

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Risk Management (Narrative) (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015	Dec. 31, 2015
Derivative [Line Items]
Collateral posted for commodity derivative instruments	$ 5.0		$ 5.0		$ 16.8
Price Risk Contracts | Maximum
Derivative [Line Items]
Remaining maturity			34 months
Percent of contracts expiring in the next twelve months			82.00%
Commodity contract
Derivative [Line Items]
Gain (loss) on derivative instruments not designated as hedging	1.3	$ 2.9	$ 2.0	$ 5.3
Collateral posted for commodity derivative instruments	0.1		0.1
Commodity contract with credit contingent features
Derivative [Line Items]
Aggregate fair value of commodity derivative instruments	5.5		5.5		3.3
NYMEX Derivative Liability
Derivative [Line Items]
Aggregate fair value of commodity derivative instruments	9.3		9.3		20.8
NYMEX Margin Deposit
Derivative [Line Items]
NYMEX margin deposits	$ 6.1		$ 6.1		$ 26.7

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Fair Value Measurements (Schedule of Carrying Values and Estimated Fair Values of Senior Notes) (Details) - Crestwood Midstream Partners LP - USD ($) $ in Millions	Jun. 30, 2016	Dec. 31, 2015
Senior Notes, 2020
Debt Instrument [Line Items]
Carrying amount	$ 340.8	$ 503.3
Fair value	319.9	382.3
Senior Notes, 2022
Debt Instrument [Line Items]
Carrying amount	436.4	600.0
Fair value	400.8	437.4
Senior Notes, 2023
Debt Instrument [Line Items]
Carrying amount	700.0	700.0
Fair value	$ 645.8	$ 491.8

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Fair Value Measurements (Assets And Liabilities Measured At Fair Value On Recurring Basis) (Details) - Fair Value, Measurements, Recurring - USD ($) $ in Millions	Jun. 30, 2016	Dec. 31, 2015
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Assets from price risk management	$ 44.2	$ 58.3
SPH units	4.7	3.4
Assets, Fair Value Disclosure, Excluding Netting Adjustments	48.9	61.7
Netting agreements	(28.9)	(13.7)
Derivative Asset, Fair Value of Collateral	(5.8)	(12.0)
Assets from price risk management, total	9.5	32.6
Total assets at fair value	14.2	36.0
Liabilities from price risk management	37.7	41.5
Liabilities, Fair Value Disclosure, Excluding Netting Adjustments	37.7	41.5
Netting agreements	(28.9)	(13.7)
Derivative Liability, Fair Value of Collateral	2.1	(20.4)
Liabilities from price risk management, total	10.9	7.4
Level 1
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Assets from price risk management	0.2	0.5
SPH units	4.7	3.4
Assets, Fair Value Disclosure, Excluding Netting Adjustments	4.9	3.9
Liabilities from price risk management	0.2	0.2
Liabilities, Fair Value Disclosure, Excluding Netting Adjustments	0.2	0.2
Level 2
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Assets from price risk management	44.0	57.8
SPH units	0.0	0.0
Assets, Fair Value Disclosure, Excluding Netting Adjustments	44.0	57.8
Liabilities from price risk management	37.5	41.3
Liabilities, Fair Value Disclosure, Excluding Netting Adjustments	37.5	41.3
Level 3
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Assets from price risk management	0.0	0.0
SPH units	0.0	0.0
Assets, Fair Value Disclosure, Excluding Netting Adjustments	0.0	0.0
Liabilities from price risk management	0.0	0.0
Liabilities, Fair Value Disclosure, Excluding Netting Adjustments	$ 0.0	$ 0.0

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Long-Term Debt (Components Of Long-Term Debt) (Details) - USD ($) $ in Millions	Jun. 30, 2016	Dec. 31, 2015
Debt Instrument [Line Items]
Other	$ 0.0	$ 0.2
Deferred Finance Costs, Net	37.6	40.9
Total debt	1,582.5	2,502.9
Less: current portion	0.9	1.1
Total long-term debt, less current portion	1,581.6	2,501.8
Senior Notes | Senior Notes, 2020
Debt Instrument [Line Items]
Senior notes	338.8	500.0
Senior Notes | Senior Notes, 2022
Debt Instrument [Line Items]
Senior notes	436.4	600.0
Senior Notes | Senior Notes, 2023
Debt Instrument [Line Items]
Senior notes	700.0	700.0
Fair value adjustment of 2020 Senior Notes | Senior Notes, 2020
Debt Instrument [Line Items]
Fair value adjustment	2.0	3.3
Other
Debt Instrument [Line Items]
Other	3.9	5.3
Revolving Credit Facility | Crestwood Midstream Revolver
Debt Instrument [Line Items]
Credit agreement outstanding carrying value	139.0	735.0
Crestwood Midstream Partners LP
Debt Instrument [Line Items]
Total debt	1,582.5	2,502.7
Less: current portion	0.9	0.9
Total long-term debt, less current portion	1,581.6	2,501.8
Crestwood Midstream Partners LP | Senior Notes, 2020
Debt Instrument [Line Items]
Senior notes	340.8	503.3
Crestwood Midstream Partners LP | Senior Notes, 2022
Debt Instrument [Line Items]
Senior notes	436.4	600.0
Crestwood Midstream Partners LP | Senior Notes, 2023
Debt Instrument [Line Items]
Senior notes	$ 700.0	$ 700.0

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Long-Term Debt (Narrative) (Detail) $ in Millions						1 Months Ended	3 Months Ended		6 Months Ended
	May 13, 2016 USD ($)	Feb. 12, 2016 USD ($)	May 15, 2015 USD ($)	Feb. 13, 2015 USD ($)	Feb. 14, 2014 USD ($)	Jun. 30, 2016 USD ($)	Jun. 30, 2016 USD ($)	Jun. 30, 2015 USD ($)	Jun. 30, 2016 USD ($)	Jun. 30, 2015 USD ($)	Dec. 31, 2015 USD ($)
Debt Instrument [Line Items]
Distribution Made to Limited Partner, Cash Distributions Paid	$ 41.4	$ 95.6	$ 25.7	$ 25.8					$ 137.0	$ 51.5
Senior Secured Leverage Ratio						0.34	0.34		0.34
Repayments of Senior Debt						$ 312.9
Gains (Losses) on Extinguishment of Debt							$ 10.0	$ (17.1)	$ 10.0	(17.1)
Repayments of Long-term Debt									$ 1,987.7	2,030.6
Senior Secured Leverage Ratio, maximum						3.75	3.75		3.75
Crestwood Midstream Revolver
Debt Instrument [Line Items]
Consolidated Leverage Ratio Maximum									5.50
Crestwood Midstream Revolver | Revolving Credit Facility
Debt Instrument [Line Items]
Letters of credit outstanding						$ 62.1	$ 62.1		$ 62.1		$ 62.2
Debt Instrument, Unused Borrowing Capacity, Amount						613.9	613.9		613.9
Credit agreement outstanding carrying value						$ 139.0	$ 139.0		$ 139.0		$ 735.0
Total Funded Debt to Consolidated Ebitda									3.99
Consolidated Ebitda To Consolidated Interest Expense									3.82
Debt, Weighted Average Interest Rate						3.30%	3.30%		3.30%		2.70%
Interest Coverage Ratio Minimum									2.50
Crestwood Midstream Revolver | Revolving Credit Facility | Minimum
Debt Instrument [Line Items]
Debt, Weighted Average Interest Rate						3.21%	3.21%		3.21%		2.70%
Crestwood Midstream Revolver | Revolving Credit Facility | Maximum
Debt Instrument [Line Items]
Debt, Weighted Average Interest Rate						5.25%	5.25%		5.25%		5.00%
Senior Notes, 2020 | Senior Notes
Debt Instrument [Line Items]
Extinguishment of Debt, Amount						$ 161.2
Interest Paid						4.5
Senior notes						338.8	$ 338.8		$ 338.8		$ 500.0
Senior Notes, 2022 | Senior Notes
Debt Instrument [Line Items]
Extinguishment of Debt, Amount						163.6
Interest Paid						2.6
Senior notes						436.4	436.4		436.4		600.0
Senior Notes, 2023 | Senior Notes
Debt Instrument [Line Items]
Senior notes						$ 700.0	$ 700.0		$ 700.0		700.0
Debt Instrument, Interest Rate, Stated Percentage						6.25%	6.25%		6.25%
Crestwood Midstream Partners LP | Senior Notes, 2023 | Senior Notes
Debt Instrument [Line Items]
Long-term Debt						$ 700.0	$ 700.0		$ 700.0
Proceeds from Issuance of Debt									688.3
Crestwood Midstream Partners LP
Debt Instrument [Line Items]
Distribution Made to Limited Partner, Cash Distributions Paid			$ 74.3		$ 74.3					148.6
Gains (Losses) on Extinguishment of Debt							10.0	$ (17.1)	10.0	(17.1)
Repayments of Long-term Debt									1,987.5	$ 1,713.2
Crestwood Midstream Partners LP | Senior Notes, 2020
Debt Instrument [Line Items]
Senior notes						340.8	340.8		340.8		503.3
Crestwood Midstream Partners LP | Senior Notes, 2022
Debt Instrument [Line Items]
Senior notes						436.4	436.4		436.4		600.0
Crestwood Midstream Partners LP | Senior Notes, 2023
Debt Instrument [Line Items]
Senior notes						$ 700.0	$ 700.0		$ 700.0		$ 700.0

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Earnings Per Limited Partner Unit (Details) - shares	3 Months Ended	6 Months Ended
	Jun. 30, 2016	Jun. 30, 2016
Preferred Units
Earnings Per Share, Basic, by Common Class, Including Two Class Method [Line Items]
Units excluded from dilutive earnings per share	6,355,936	6,284,885
Preferred Units | Crestwood Niobrara LLC
Earnings Per Share, Basic, by Common Class, Including Two Class Method [Line Items]
Units excluded from dilutive earnings per share	8,438,849	8,438,849
Subordinated Units
Earnings Per Share, Basic, by Common Class, Including Two Class Method [Line Items]
Units excluded from dilutive earnings per share	438,789	438,789

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Partners' Capital (Schedule of Partners' Capital Account, Distriubtions) (Details) - USD ($) $ / shares in Units, $ in Millions											6 Months Ended
	May 13, 2016	May 06, 2016	Feb. 12, 2016	Feb. 05, 2016	May 15, 2015	May 08, 2015	Feb. 13, 2015	Feb. 06, 2015	Feb. 14, 2014	Feb. 07, 2014	Jun. 30, 2016	Jun. 30, 2015
Distribution Made to Limited Partner [Line Items]
Distribution Made to Limited Partner, Date of Record		May 06, 2016		Feb. 05, 2016		May 08, 2015		Feb. 06, 2015
Distribution Made to Limited Partner, Distribution Date	May 13, 2016		Feb. 12, 2016		May 15, 2015		Feb. 13, 2015
Distribution Made to Member or Limited Partner, Distributions Paid, Per Unit	$ 0.60		$ 1.375		$ 1.375		$ 1.375
Distribution Made to Limited Partner, Cash Distributions Paid	$ 41.4		$ 95.6		$ 25.7		$ 25.8				$ 137.0	$ 51.5
Crestwood Midstream Partners LP
Distribution Made to Limited Partner [Line Items]
Distribution Made to Limited Partner, Date of Record						May 08, 2015				Feb. 06, 2015
Distribution Made to Limited Partner, Distribution Date					May 15, 2015				Feb. 13, 2015
Distribution Made to Member or Limited Partner, Distributions Paid, Per Unit					$ 410.00				$ 0.41
Distribution Made to Limited Partner, Cash Distributions Paid					$ 74.3				$ 74.3			$ 148.6

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Partners' Capital (Components of Net Income (Loss) Attributable to Non-Controlling Interests) (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015
Distribution Made to Limited Partner [Line Items]
Net income attributable to non-controlling partners in subsidiaries	$ 6.0	$ (256.0)	$ 11.9	$ (246.2)
Crestwood Midstream Partners LP
Distribution Made to Limited Partner [Line Items]
Net income attributable to non-controlling partners in subsidiaries	6.0	5.7	11.9	11.3
Crestwood Niobrara LLC
Distribution Made to Limited Partner [Line Items]
Net income attributable to non-controlling partners in subsidiaries	6.0	5.7	11.9	11.3
Preferred Units, Class A | Crestwood Midstream Partners LP
Distribution Made to Limited Partner [Line Items]
Net income attributable to non-controlling partners in subsidiaries	0.0	7.5	0.0	16.7
Limited Partner [Member] | Crestwood Midstream Partners LP
Distribution Made to Limited Partner [Line Items]
Net income attributable to non-controlling partners in subsidiaries	$ 0.0	$ (269.2)	$ 0.0	$ (274.2)

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Partners' Capital (Narrative) (Details) - USD ($) $ / shares in Units, $ in Millions												1 Months Ended	3 Months Ended		6 Months Ended
	Jul. 21, 2016	May 13, 2016	May 06, 2016	Feb. 12, 2016	Feb. 05, 2016	May 15, 2015	May 08, 2015	Feb. 13, 2015	Feb. 06, 2015	Feb. 14, 2014	Feb. 07, 2014	Jul. 31, 2016	Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015	Jun. 15, 2016	Dec. 31, 2015
Distribution Made to Limited Partner [Line Items]
Distribution Made to Limited Partner, Distribution Date		May 13, 2016		Feb. 12, 2016		May 15, 2015		Feb. 13, 2015
Distribution Made to Limited Partner, Date of Record			May 06, 2016		Feb. 05, 2016		May 08, 2015		Feb. 06, 2015
Incentive Distribution, Distribution															$ 137.0	$ 51.5
Limited Partners' Capital Account, Distribution Amount																20.9
Preferred Stock Dividends, Shares															2,841,114
Net Income (Loss) Attributable to Noncontrolling Interest													$ 6.0	$ (256.0)	$ 11.9	(246.2)
Dividends, Paid-in-kind															25.9
Common Units Available for Issuance																	7,290,552
Payments of Ordinary Dividends, Noncontrolling Interest															7.6	152.4
Distribution Made to Limited Partner, Cash Distributions Paid		$ 41.4		$ 95.6		$ 25.7		$ 25.8							$ 137.0	51.5
Preferred Units, Issued													63,559,359		63,559,359			60,718,245
Crestwood Equity Partners LP
Distribution Made to Limited Partner [Line Items]
Incentive Distribution Rights, Ownership Percentage															100.00%
Crestwood Midstream Partners LP
Distribution Made to Limited Partner [Line Items]
Distribution Made to Limited Partner, Distribution Date						May 15, 2015				Feb. 13, 2015
Distribution Made to Limited Partner, Date of Record							May 08, 2015				Feb. 06, 2015
Incentive Distribution, Distribution															$ 148.2	$ 225.2
Preferred Stock Dividends, Shares																838,228
Net Income (Loss) Attributable to Noncontrolling Interest													$ 6.0	5.7	11.9	$ 11.3
Dividends, Paid-in-kind																21.0
Payments of Ordinary Dividends, Noncontrolling Interest															0.0	0.0
Distribution Made to Limited Partner, Cash Distributions Paid						$ 74.3				$ 74.3						148.6
Distribution Made to General Partner, Cash Distributions Paid															140.6	51.9
Crestwood Niobrara LLC
Distribution Made to Limited Partner [Line Items]
Net Income (Loss) Attributable to Noncontrolling Interest													$ 6.0	$ 5.7	11.9	11.3
Payments of Ordinary Dividends, Noncontrolling Interest															7.6	3.8
Non-Controlling Partners
Distribution Made to Limited Partner [Line Items]
Net Income (Loss) Attributable to Noncontrolling Interest															$ 11.9
Subsequent Event
Distribution Made to Limited Partner [Line Items]
Distribution Made to Limited Partner, Distribution Date	Aug. 12, 2016
Distribution Made to Limited Partner, Date of Record	Aug. 05, 2016
Preferred Stock Dividends, Shares	1,470,029
Dividends, Paid-in-kind	$ 13.4
Payments of Ordinary Dividends, Noncontrolling Interest												$ 3.8
Cash Distribution
Distribution Made to Limited Partner [Line Items]
Limited Partners' Capital Account, Distribution Amount																$ 148.6
Cash Distribution | Subsequent Event
Distribution Made to Limited Partner [Line Items]
Distribution Made to Limited Partner, Distributions Declared, Per Unit	$ 0.6

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Commitments and Contingencies (Details) $ in Millions	6 Months Ended
	Jun. 30, 2016 USD ($)	Dec. 31, 2015 USD ($)	Nov. 08, 2013 bbl people
Purchase Commitment, Excluding Long-term Commitment [Line Items]
Self Insurance Reserve	$ 17.8	$ 17.2
Self Insurance Reserve Expected To Be Paid Subsequent To Next Fiscal Year	$ 11.3
Loss Contingency, New Claims Filed, Number	39
Loss Contingency, Estimate of Possible Loss	$ 7.0
Payments for Other Taxes	8.6
Accrued property taxes	12.3	4.8
Loss Contingency Accrual, at Carrying Value		0.1
Arrow Acquisition Class Action Lawsuit
Purchase Commitment, Excluding Long-term Commitment [Line Items]
Loss Contingency, Loss of Life, Number | people			47
Minimum | Arrow Acquisition Class Action Lawsuit
Purchase Commitment, Excluding Long-term Commitment [Line Items]
Barrels of Oil Equivalents Spilled | bbl			50,000
Tres Palacios Holdings LLC
Purchase Commitment, Excluding Long-term Commitment [Line Items]
Loss Contingency, Estimate of Possible Loss	2.0
Crestwood Midstream Partners LP
Purchase Commitment, Excluding Long-term Commitment [Line Items]
Self Insurance Reserve	12.4	11.4
Self Insurance Reserve Expected To Be Paid Subsequent To Next Fiscal Year	7.1
Accrued property taxes	7.3	$ 4.8
Tres Palacios
Purchase Commitment, Excluding Long-term Commitment [Line Items]
Accrued property taxes	$ 3.5

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Commitments and Contingencies Environmental Compliance (Details) $ in Millions	6 Months Ended	12 Months Ended
	Jun. 30, 2016 USD ($)	Dec. 31, 2014 Release	Dec. 31, 2015 USD ($) bbl	Sep. 15, 2015 USD ($)	May 06, 2015 bbl
Site Contingency [Line Items]
Loss Contingency, Range of Possible Loss, Maximum				$ 1.1
Fort Berthold Indian Reservation
Site Contingency [Line Items]
Site Contingency, Loss Exposure, Number of Releases of Produced Water | Release		3
Site Contingency, Loss Exposure, Release of Produced Water | bbl			28,000		5,200
Accrual for Environmental Loss Contingencies	$ 2.6		$ 1.7
Site Contingency, Loss Exposure in Excess of Accrual, Low Estimate	2.6
Site Contingency, Loss Exposure in Excess of Accrual, High Estimate	$ 4.9

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Related Party Transactions (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015	Dec. 31, 2015
Related Party Transaction [Line Items]
Gathering and processing revenues at CEQP and CMLP	$ 0.7	$ 1.1	$ 1.4	$ 2.1
General and administrative expenses charged by (from) CEQP to Crestwood Holdings, net(3)	1.0	0.7	1.7	1.6
Affiliated Entity
Related Party Transaction [Line Items]
Related party receivables	2.1		2.1		$ 1.7
Gathering and processing revenues at CEQP and CMLP	0.7	1.1	1.4	2.1
Gathering and processing costs of product/services sold at CEQP and CMLP(1)	4.4	7.7	8.7	16.0
General and administrative expenses charged by CEQP to CMLP, net(2)	3.2	14.4	6.9	31.8
Related Party Transaction, Due from (to) Related Party [Abstract]
Accounts payable	6.3		6.3		4.0
Crestwood Equity Partners LP
Related Party Transaction [Line Items]
General and administrative expenses charged by (from) CEQP to Crestwood Holdings, net(3)	(0.2)	0.1	(0.1)	0.2
Crestwood Midstream Partners LP
Related Party Transaction [Line Items]
Gathering and processing revenues at CEQP and CMLP	0.7	1.1	1.4	2.1
Crestwood Midstream Partners LP | Affiliated Entity
Related Party Transaction [Line Items]
Related party receivables	2.1		2.1		1.7
General and administrative expenses charged by CEQP to CMLP, net(2)	0.7		1.5
Related Party Transaction, Due from (to) Related Party [Abstract]
Accounts payable	3.8		3.8		$ 1.5
Crestwood LTIP | Crestwood Midstream Partners LP
Related Party Transaction [Line Items]
Allocated Share-based Compensation Expense	$ 3.9	$ 2.2	8.4	$ 4.4
Crestwood LTIP | Crestwood Holdings [Member]
Related Party Transaction [Line Items]
Allocated Share-based Compensation Expense			0.9
Stagecoach Gas Services LLC
Related Party Transaction [Line Items]
General and administrative expenses charged by (from) CEQP to Crestwood Holdings, net(3)			$ 0.3

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Segments (Reconciliation of Net Income (Loss) to EBITDA) (Details) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2016 USD ($)	Jun. 30, 2015 USD ($)	Jun. 30, 2016 USD ($) segment	Jun. 30, 2015 USD ($)
Segment Reporting, Other Significant Reconciling Item [Line Items]
Number of Operating Segments | segment			3
Net loss	$ (37.1)	$ (296.0)	$ (130.8)	$ (277.9)
Interest and debt expense, net	34.3	35.4	70.4	69.0
Gains (Losses) on Extinguishment of Debt	(10.0)	17.1	(10.0)	17.1
Provision (benefit) for income taxes	0.0	(0.3)	0.0	0.1
Depreciation, amortization and accretion	64.4	74.8	126.7	149.0
EBITDA	51.6	(169.0)	56.3	(42.7)
Crestwood Midstream Partners LP
Segment Reporting, Other Significant Reconciling Item [Line Items]
Net loss	(35.6)	(72.8)	(130.9)	(43.7)
Interest and debt expense, net	34.3	32.6	70.4	62.5
Gains (Losses) on Extinguishment of Debt	(10.0)	17.1	(10.0)	17.1
Provision (benefit) for income taxes	0.2	0.1	0.0	0.5
Depreciation, amortization and accretion	67.1	69.5	132.0	138.3
EBITDA	$ 56.0	$ 46.5	$ 61.5	$ 174.7

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Segments (Summary Of Segment Information) (Details) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2016 USD ($)	Jun. 30, 2015 USD ($)	Jun. 30, 2016 USD ($) segment	Jun. 30, 2015 USD ($)	Dec. 31, 2015 USD ($)
Net loss	$ (37.1)	$ (296.0)	$ (130.8)	$ (277.9)
Interest and debt expense, net	34.3	35.4	70.4	69.0
Gains (Losses) on Extinguishment of Debt	(10.0)	17.1	$ (10.0)	17.1
Number of Operating Segments | segment			3
Provision (benefit) for income taxes	0.0	(0.3)	$ 0.0	0.1
Depreciation, amortization and accretion	64.4	74.8	126.7	149.0
Segment Reporting Information, Additional Information [Abstract]
Operating revenues	601.9	641.5	1,137.9	1,373.0
Intersegment Revenues	0.0	0.0	0.0	0.0
Costs of product/services sold	450.0	459.5	813.4	989.2
Operations and maintenance	45.0	43.9	86.8	94.5
General and administrative	28.9	30.6	51.9	58.1
Goodwill impairment	0.0	(281.0)	(109.7)	(281.0)
Loss on long-lived assets, net	(32.7)	(0.6)	(32.7)	(1.6)
Earnings from unconsolidated affiliates, net	6.2	5.0	12.7	8.4
Other income, net	0.1	0.1	0.2	0.3
EBITDA	51.6	(169.0)	56.3	(42.7)
Goodwill	249.5		249.5		$ 1,085.5
Total assets	4,593.4		4,593.4		5,762.8
Cash expenditures for property, plant and equipment	20.6	36.1	76.2	83.5
Gathering and Processing Operations
Segment Reporting Information, Additional Information [Abstract]
Operating revenues	269.5	346.8	508.4	697.1
Intersegment Revenues	30.6	33.8	51.1	43.9
Costs of product/services sold	226.3	293.1	406.1	559.8
Operations and maintenance	20.9	22.3	38.7	46.4
General and administrative	0.0	0.0	0.0	0.0
Goodwill impairment		(220.7)	(8.6)	(220.7)
Loss on long-lived assets, net	0.0	(0.6)	0.0	(0.9)
Earnings from unconsolidated affiliates, net	5.9	1.1	11.0	3.6
Other income, net	0.0	0.0	0.0	0.0
EBITDA	58.8	(155.0)	117.1	(83.2)
Goodwill	45.9		45.9
Total assets	2,394.1		2,394.1
Cash expenditures for property, plant and equipment	4.2	28.4	48.5	64.6
Storage and Transportation
Segment Reporting Information, Additional Information [Abstract]
Operating revenues	53.8	68.5	113.2	136.1
Intersegment Revenues	1.1	0.0	1.5	0.0
Costs of product/services sold	1.9	5.3	4.8	10.6
Operations and maintenance	8.5	5.9	15.7	12.3
General and administrative	0.0	0.0	0.0	0.0
Goodwill impairment		0.0	(13.7)	0.0
Loss on long-lived assets, net	(32.7)	0.0	(32.7)	(0.7)
Earnings from unconsolidated affiliates, net	0.3	3.9	1.7	4.8
Other income, net	0.0	0.0	0.0	0.0
EBITDA	12.1	61.2	49.5	117.3
Goodwill	31.2		31.2
Total assets	1,191.2		1,191.2
Cash expenditures for property, plant and equipment	11.6	3.9	14.9	8.0
Marketing Supply and Logistics
Segment Reporting Information, Additional Information [Abstract]
Operating revenues	278.6	226.2	516.3	539.8
Intersegment Revenues	(31.7)	(33.8)	(52.6)	(43.9)
Costs of product/services sold	221.8	161.1	402.5	418.8
Operations and maintenance	15.6	15.7	32.4	35.8
General and administrative	0.0	0.0	0.0	0.0
Goodwill impairment		(60.3)	(87.4)	(60.3)
Loss on long-lived assets, net	0.0	0.0	0.0	0.0
Earnings from unconsolidated affiliates, net	0.0	0.0	0.0	0.0
Other income, net	0.0	0.0	0.0	0.0
EBITDA	9.5	(44.7)	(58.6)	(19.0)
Goodwill	172.4		172.4
Total assets	974.8		974.8
Cash expenditures for property, plant and equipment	4.7	3.6	11.8	10.5
Corporate
Segment Reporting Information, Additional Information [Abstract]
Operating revenues	0.0	0.0	0.0	0.0
Intersegment Revenues	0.0	0.0	0.0	0.0
Costs of product/services sold	0.0	0.0	0.0	0.0
Operations and maintenance	0.0	0.0	0.0	0.0
General and administrative	28.9	30.6	51.9	58.1
Goodwill impairment		0.0	0.0	0.0
Loss on long-lived assets, net	0.0	0.0	0.0	0.0
Earnings from unconsolidated affiliates, net	0.0	0.0	0.0	0.0
Other income, net	0.1	0.1	0.2	0.3
EBITDA	(28.8)	(30.5)	(51.7)	(57.8)
Goodwill	0.0		0.0
Total assets	33.3		33.3
Cash expenditures for property, plant and equipment	0.1	0.2	1.0	0.4
Crestwood Midstream Partners LP
Net loss	(35.6)	(72.8)	(130.9)	(43.7)
Interest and debt expense, net	34.3	32.6	70.4	62.5
Gains (Losses) on Extinguishment of Debt	(10.0)	17.1	(10.0)	17.1
Provision (benefit) for income taxes	0.2	0.1	0.0	0.5
Depreciation, amortization and accretion	67.1	69.5	132.0	138.3
Segment Reporting Information, Additional Information [Abstract]
Operating revenues	601.9	641.5	1,137.9	1,373.0
Intersegment Revenues	0.0	0.0	0.0	0.0
Costs of product/services sold	450.0	459.5	813.4	989.2
Operations and maintenance	41.4	43.9	83.1	94.5
General and administrative	28.0	27.3	50.2	52.9
Goodwill impairment	0.0	(68.6)	(109.7)	(68.6)
Loss on long-lived assets, net	(32.7)	(0.7)	(32.7)	(1.5)
Earnings from unconsolidated affiliates, net	6.2	5.0	12.7	8.4
EBITDA	56.0	46.5	61.5	174.7
Goodwill	249.5		249.5		1,085.5
Total assets	4,785.9		4,785.9		$ 5,963.6
Cash expenditures for property, plant and equipment	20.6	36.1	76.2	83.5
Crestwood Midstream Partners LP | Gathering and Processing Operations
Segment Reporting Information, Additional Information [Abstract]
Operating revenues	269.5	346.8	508.4	697.1
Intersegment Revenues	30.6	33.8	51.1	43.9
Costs of product/services sold	226.3	293.1	406.1	559.8
Operations and maintenance	20.9	22.3	38.7	46.4
General and administrative	0.0	0.0	0.0	0.0
Goodwill impairment		(8.3)	(8.6)	(8.3)
Loss on long-lived assets, net	0.0	(0.6)	0.0	(0.9)
Earnings from unconsolidated affiliates, net	5.9	1.1	11.0	3.6
EBITDA	58.8	57.4	117.1	129.2
Goodwill	45.9		45.9
Total assets	2,603.3		2,603.3
Cash expenditures for property, plant and equipment	4.2	28.4	48.5	64.6
Crestwood Midstream Partners LP | Storage and Transportation
Segment Reporting Information, Additional Information [Abstract]
Operating revenues	53.8	68.5	113.2	136.1
Intersegment Revenues	1.1	0.0	1.5	0.0
Costs of product/services sold	1.9	5.3	4.8	10.6
Operations and maintenance	4.9	5.9	12.0	12.3
General and administrative	0.0	0.0	0.0	0.0
Goodwill impairment		0.0	(13.7)	0.0
Loss on long-lived assets, net	(32.7)	(0.1)	(32.7)	(0.6)
Earnings from unconsolidated affiliates, net	0.3	3.9	1.7	4.8
EBITDA	15.7	61.1	53.2	117.4
Goodwill	31.2		31.2
Total assets	1,188.9		1,188.9
Cash expenditures for property, plant and equipment	11.6	3.9	14.9	8.0
Crestwood Midstream Partners LP | Marketing Supply and Logistics
Segment Reporting Information, Additional Information [Abstract]
Operating revenues	278.6	226.2	516.3	539.8
Intersegment Revenues	(31.7)	(33.8)	(52.6)	(43.9)
Costs of product/services sold	221.8	161.1	402.5	418.8
Operations and maintenance	15.6	15.7	32.4	35.8
General and administrative	0.0	0.0	0.0	0.0
Goodwill impairment		(60.3)	(87.4)	(60.3)
Loss on long-lived assets, net	0.0	0.0	0.0	0.0
Earnings from unconsolidated affiliates, net	0.0	0.0	0.0	0.0
EBITDA	9.5	(44.7)	(58.6)	(19.0)
Goodwill	172.4		172.4
Total assets	974.8		974.8
Cash expenditures for property, plant and equipment	4.7	3.6	11.8	10.5
Crestwood Midstream Partners LP | Corporate
Segment Reporting Information, Additional Information [Abstract]
Operating revenues	0.0	0.0	0.0	0.0
Intersegment Revenues	0.0	0.0	0.0	0.0
Costs of product/services sold	0.0	0.0	0.0	0.0
Operations and maintenance	0.0	0.0	0.0	0.0
General and administrative	28.0	27.3	50.2	52.9
Goodwill impairment		0.0	0.0	0.0
Loss on long-lived assets, net	0.0	0.0	0.0	0.0
Earnings from unconsolidated affiliates, net	0.0	0.0	0.0	0.0
EBITDA	(28.0)	(27.3)	(50.2)	(52.9)
Goodwill	0.0		0.0
Total assets	18.9		18.9
Cash expenditures for property, plant and equipment	$ 0.1	$ 0.2	$ 1.0	$ 0.4

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Segments (Narrative) (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015
Crestwood Equity Partners LP
Segment Reporting Information [Line Items]
Interest, Taxes, Depreciation and Amortization included in Earnings from Equity Method Investments	$ 4.4	$ 0.7	$ 7.0	$ 3.8
Crestwood Midstream Partners LP
Segment Reporting Information [Line Items]
Interest, Taxes, Depreciation and Amortization included in Earnings from Equity Method Investments	$ 4.4	$ 0.7	$ 7.0	$ 3.8

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Condensed Consolidating Financial Information (Balance Sheet) (Details) - USD ($) $ in Millions	Jun. 30, 2016	Dec. 31, 2015	Jun. 30, 2015	Dec. 31, 2014	Dec. 31, 2012
Current assets:
Cash	$ 0.9	$ 0.5	$ 1.3		$ 8.8
Accounts receivable	247.5	236.5
Inventory	43.5	44.5
Assets Held-for-sale, Not Part of Disposal Group, Current	55.0	0.0
Total current assets	367.3	335.8
Property, plant and equipment, net	2,148.0	3,310.8
Investment	1,099.1	254.3
Other assets	7.7	7.2
Total assets	4,593.4	5,762.8
Current liabilities:
Accounts payable	164.5	144.1
Total current liabilities	277.5	258.2
Long-term liabilities:
Long-term debt, less current portion (Note 7)	1,581.6	2,501.8
Other long-term liabilities	45.1	47.5
Deferred income taxes	7.8	8.4
Total partners’ capital	2,681.4	2,946.9
Total liabilities and partners’ capital	4,593.4	5,762.8
Eliminations
Current assets:
Cash	0.0	0.0	0.0	$ 0.0
Accounts receivable	0.0	0.0
Inventory	0.0	0.0
Assets Held-for-sale, Not Part of Disposal Group, Current	0.0
Other	0.0	0.0
Total current assets	0.0	0.0
Property, plant and equipment, net	0.0	0.0
Intangible Assets, Net (Including Goodwill)	0.0	0.0
Investment in consolidated affiliates	(4,310.1)	(5,506.8)
Investment	0.0	0.0
Other assets	0.0	0.0
Total assets	(4,310.1)	(5,506.8)
Current liabilities:
Accounts payable	0.0	0.0
Total current liabilities	0.0	0.0
Total current liabilities	0.0	0.0
Long-term liabilities:
Long-term debt, less current portion (Note 7)	0.0	0.0
Other long-term liabilities	0.0	0.0
Deferred income taxes	0.0	0.0
Partners' capital	(4,310.1)	(5,506.8)
Interest of non-controlling partners in subsidiary	0.0	0.0
Total partners’ capital	(4,310.1)	(5,506.8)
Total liabilities and partners’ capital	(4,310.1)	(5,506.8)
Parent Company, Crestwood Midstream Partners, LP | Reportable Legal Entities
Current assets:
Cash	0.2	0.1	0.0	0.0
Accounts receivable	0.0	0.0
Inventory	0.0	0.0
Assets Held-for-sale, Not Part of Disposal Group, Current	0.0
Other	0.0	0.0
Total current assets	0.2	0.1
Property, plant and equipment, net	0.0	0.0
Intangible Assets, Net (Including Goodwill)	0.0	0.0
Investment in consolidated affiliates	4,310.1	5,506.8
Investment	0.0	0.0
Other assets	0.0	0.0
Total assets	4,310.3	5,506.9
Current liabilities:
Accounts payable	0.0	0.0
Total current liabilities	23.4	26.4
Total current liabilities	23.4	26.4
Long-term liabilities:
Long-term debt, less current portion (Note 7)	1,580.1	2,498.9
Other long-term liabilities	0.0	0.0
Deferred income taxes	0.0	0.0
Partners' capital	2,706.8	2,981.6
Interest of non-controlling partners in subsidiary	0.0	0.0
Total partners’ capital	2,706.8	2,981.6
Total liabilities and partners’ capital	4,310.3	5,506.9
Guarantor Subsidiaries | Reportable Legal Entities
Current assets:
Cash	0.0	0.0	0.8	7.6
Accounts receivable	242.4	236.0
Inventory	43.5	44.5
Assets Held-for-sale, Not Part of Disposal Group, Current	55.0
Other	19.8	52.5
Total current assets	360.7	333.0
Property, plant and equipment, net	2,355.9	3,525.7
Intangible Assets, Net (Including Goodwill)	965.2	1,846.9
Investment in consolidated affiliates	0.0	0.0
Investment	0.0	0.0
Other assets	2.9	3.1
Total assets	3,684.7	5,708.7
Current liabilities:
Accounts payable	161.8	141.3
Total current liabilities	82.9	85.2
Total current liabilities	244.7	226.5
Long-term liabilities:
Long-term debt, less current portion (Note 7)	1.5	2.9
Other long-term liabilities	40.9	43.3
Deferred income taxes	0.7	0.4
Partners' capital	3,396.9	5,435.6
Interest of non-controlling partners in subsidiary	0.0	0.0
Total partners’ capital	3,396.9	5,435.6
Total liabilities and partners’ capital	3,684.7	5,708.7
Non-Guarantor Subsidiaries | Reportable Legal Entities
Current assets:
Cash	0.0	0.0	0.0	0.0
Accounts receivable	1.9	0.5
Inventory	0.0	0.0
Assets Held-for-sale, Not Part of Disposal Group, Current	0.0
Other	0.0	0.0
Total current assets	1.9	0.5
Property, plant and equipment, net	0.0	0.0
Intangible Assets, Net (Including Goodwill)	0.0	0.0
Investment in consolidated affiliates	0.0	0.0
Investment	1,099.1	254.3
Other assets	0.0	0.0
Total assets	1,101.0	254.8
Current liabilities:
Accounts payable	0.0	0.1
Total current liabilities	0.0	0.0
Total current liabilities	0.0	0.1
Long-term liabilities:
Long-term debt, less current portion (Note 7)	0.0	0.0
Other long-term liabilities	0.0	0.0
Deferred income taxes	0.0	0.0
Partners' capital	913.2	71.2
Interest of non-controlling partners in subsidiary	187.8	183.5
Total partners’ capital	1,101.0	254.7
Total liabilities and partners’ capital	1,101.0	254.8
Crestwood Midstream Partners LP
Current assets:
Cash	0.2	0.1	$ 0.8	$ 7.6	$ 7.6
Accounts receivable	244.3	236.5
Inventory	43.5	44.5
Assets Held-for-sale, Not Part of Disposal Group, Current	55.0	0.0
Other	19.8	52.5
Total current assets	362.8	333.6
Property, plant and equipment, net	2,355.9	3,525.7
Intangible Assets, Net (Including Goodwill)	965.2	1,846.9
Investment in consolidated affiliates	0.0	0.0
Investment	1,099.1	254.3
Other assets	2.9	3.1
Total assets	4,785.9	5,963.6
Current liabilities:
Accounts payable	161.8	141.4
Total current liabilities	106.3	111.6
Total current liabilities	268.1	253.0
Long-term liabilities:
Long-term debt, less current portion (Note 7)	1,581.6	2,501.8
Other long-term liabilities	40.9	43.3
Deferred income taxes	0.7	0.4
Partners' capital	2,706.8	2,981.6
Interest of non-controlling partners in subsidiary	187.8	183.5
Total partners’ capital	2,894.6	3,165.1
Total liabilities and partners’ capital	$ 4,785.9	$ 5,963.6

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Condensed Consolidating Financial Information (Statements Of Operations) (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015
Revenues	$ 601.9	$ 641.5	$ 1,137.9	$ 1,373.0
Total costs of products/services sold	450.0	459.5	813.4	989.2
Expenses:
Operations and maintenance	45.0	43.9	86.8	94.5
General and administrative	28.9	30.6	51.9	58.1
Depreciation, amortization and accretion	64.4	74.8	126.7	149.0
Loss on long-lived assets, net	(32.7)	(0.6)	(32.7)	(1.6)
Goodwill impairment	0.0	(281.0)	(109.7)	(281.0)
Operating loss	(19.1)	(248.9)	(83.3)	(200.4)
Earnings from unconsolidated affiliates, net	6.2	5.0	12.7	8.4
Interest and debt expense, net	(34.3)	(35.4)	(70.4)	(69.0)
Loss before income taxes	(37.1)	(296.3)	(130.8)	(277.8)
Provision (benefit) for income taxes	0.0	(0.3)	0.0	0.1
Net loss	(37.1)	(296.0)	(130.8)	(277.9)
Net income attributable to non-controlling partners in subsidiaries	6.0	(256.0)	11.9	(246.2)
Net income (loss) attributable to parent	(43.1)	(40.0)	(142.7)	(31.7)
Net income (loss) attributable to preferred unit holders	8.1	0.0	9.7	0.0
Net loss attributable to partners	(51.2)	(40.0)	(152.4)	(31.7)
Gains (Losses) on Extinguishment of Debt	10.0	(17.1)	10.0	(17.1)
Eliminations
Revenues	0.0	0.0	0.0	0.0
Total costs of products/services sold	0.0	0.0	0.0	0.0
Expenses:
Operations and maintenance	0.0	0.0	0.0	0.0
General and administrative	0.0	0.0	0.0	0.0
Depreciation, amortization and accretion	0.0	0.0	0.0	0.0
Costs and Expenses	0.0	0.0	0.0	0.0
Loss on long-lived assets, net	0.0	0.0	0.0	0.0
Goodwill impairment	0.0	0.0	0.0	0.0
Operating loss	0.0	0.0	0.0	0.0
Earnings from unconsolidated affiliates, net	0.0	0.0	0.0	0.0
Interest and debt expense, net	0.0	0.0	0.0	0.0
Loss from unconsolidated affiliates	(11.9)	5.8	29.6	(66.8)
Loss before income taxes	(11.9)	5.8		(66.8)
Provision (benefit) for income taxes	0.0	0.0		0.0
Net loss	(11.9)	5.8	29.6	(66.8)
Net income attributable to non-controlling partners in subsidiaries	0.0	0.0	0.0	0.0
Net income (loss) attributable to parent	(11.9)	5.8	29.6	(66.8)
Net income (loss) attributable to preferred unit holders		0.0		0.0
Net loss attributable to partners		5.8		(66.8)
Gains (Losses) on Extinguishment of Debt	0.0	0.0	0.0	0.0
Parent Company, Crestwood Midstream Partners, LP | Reportable Legal Entities
Revenues	0.0	0.0	0.0	0.0
Total costs of products/services sold	0.0	0.0	0.0	0.0
Expenses:
Operations and maintenance	0.0	0.0	0.0	0.0
General and administrative	23.2	16.4	40.9	29.8
Depreciation, amortization and accretion	0.0	0.9	0.0	1.1
Costs and Expenses	23.2	17.3	40.9	30.9
Loss on long-lived assets, net	0.0	0.0	0.0	0.0
Goodwill impairment	0.0	0.0	0.0	0.0
Operating loss	(23.2)	(17.3)	(40.9)	(30.9)
Earnings from unconsolidated affiliates, net	0.0	0.0	0.0	0.0
Interest and debt expense, net	(34.3)	(32.6)	(70.4)	(62.5)
Loss from unconsolidated affiliates	11.9	(5.8)	(29.6)	66.8
Loss before income taxes	(35.6)	(72.8)		(43.7)
Provision (benefit) for income taxes	0.0	0.0		0.0
Net loss	(35.6)	(72.8)	(130.9)	(43.7)
Net income attributable to non-controlling partners in subsidiaries	0.0	0.0	0.0	0.0
Net income (loss) attributable to parent	(35.6)	(72.8)	(130.9)	(43.7)
Net income (loss) attributable to preferred unit holders		7.5		16.7
Net loss attributable to partners		(80.3)		(60.4)
Gains (Losses) on Extinguishment of Debt	10.0	(17.1)	10.0	(17.1)
Guarantor Subsidiaries | Reportable Legal Entities
Revenues	601.9	641.5	1,137.9	1,373.0
Total costs of products/services sold	450.0	459.5	813.4	989.2
Expenses:
Operations and maintenance	41.4	43.9	83.1	94.5
General and administrative	4.8	10.9	9.3	23.1
Depreciation, amortization and accretion	67.1	68.6	132.0	137.2
Costs and Expenses	113.3	123.4	224.4	254.8
Loss on long-lived assets, net	(32.7)	(0.7)	(32.7)	(1.5)
Goodwill impairment	0.0	(68.6)	(109.7)	(68.6)
Operating loss	5.9	(10.7)	(42.3)	58.9
Earnings from unconsolidated affiliates, net	0.0	0.0	0.0	0.0
Interest and debt expense, net	0.0	0.0	0.0	0.0
Loss from unconsolidated affiliates	0.0	0.0	0.0	0.0
Loss before income taxes	5.9	(10.7)		58.9
Provision (benefit) for income taxes	0.2	0.1		0.5
Net loss	5.7	(10.8)	(42.3)	58.4
Net income attributable to non-controlling partners in subsidiaries	0.0	0.0	0.0	0.0
Net income (loss) attributable to parent	5.7	(10.8)	(42.3)	58.4
Net income (loss) attributable to preferred unit holders		0.0		0.0
Net loss attributable to partners		(10.8)		58.4
Gains (Losses) on Extinguishment of Debt	0.0	0.0	0.0	0.0
Non-Guarantor Subsidiaries | Reportable Legal Entities
Revenues	0.0	0.0	0.0	0.0
Total costs of products/services sold	0.0	0.0	0.0	0.0
Expenses:
Operations and maintenance	0.0	0.0	0.0	0.0
General and administrative	0.0	0.0	0.0	0.0
Depreciation, amortization and accretion	0.0	0.0	0.0	0.0
Costs and Expenses	0.0	0.0	0.0	0.0
Loss on long-lived assets, net	0.0	0.0	0.0	0.0
Goodwill impairment	0.0	0.0	0.0	0.0
Operating loss	0.0	0.0	0.0	0.0
Earnings from unconsolidated affiliates, net	6.2	5.0	12.7	8.4
Interest and debt expense, net	0.0	0.0	0.0	0.0
Loss from unconsolidated affiliates	0.0	0.0	0.0	0.0
Loss before income taxes	6.2	5.0		8.4
Provision (benefit) for income taxes	0.0	0.0		0.0
Net loss	6.2	5.0	12.7	8.4
Net income attributable to non-controlling partners in subsidiaries	6.0	5.7	11.9	11.3
Net income (loss) attributable to parent	0.2	(0.7)	0.8	(2.9)
Net income (loss) attributable to preferred unit holders		0.0		0.0
Net loss attributable to partners		(0.7)		(2.9)
Gains (Losses) on Extinguishment of Debt	0.0	0.0	0.0	0.0
Crestwood Midstream Partners LP
Revenues	601.9	641.5	1,137.9	1,373.0
Total costs of products/services sold	450.0	459.5	813.4	989.2
Expenses:
Operations and maintenance	41.4	43.9	83.1	94.5
General and administrative	28.0	27.3	50.2	52.9
Depreciation, amortization and accretion	67.1	69.5	132.0	138.3
Costs and Expenses	136.5	140.7	265.3	285.7
Loss on long-lived assets, net	(32.7)	(0.7)	(32.7)	(1.5)
Goodwill impairment	0.0	(68.6)	(109.7)	(68.6)
Operating loss	(17.3)	(28.0)	(83.2)	28.0
Earnings from unconsolidated affiliates, net	6.2	5.0	12.7	8.4
Interest and debt expense, net	(34.3)	(32.6)	(70.4)	(62.5)
Loss from unconsolidated affiliates	0.0	0.0	0.0	0.0
Loss before income taxes	(35.4)	(72.7)	(130.9)	(43.2)
Provision (benefit) for income taxes	0.2	0.1	0.0	0.5
Net loss	(35.6)	(72.8)	(130.9)	(43.7)
Net income attributable to non-controlling partners in subsidiaries	6.0	5.7	11.9	11.3
Net income (loss) attributable to parent	(41.6)	(78.5)	(142.8)	(55.0)
Net income (loss) attributable to preferred unit holders	0.0	7.5	0.0	16.7
Net loss attributable to partners	(41.6)	(86.0)	(142.8)	(71.7)
Gains (Losses) on Extinguishment of Debt	$ 10.0	$ (17.1)	$ 10.0	$ (17.1)

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Condensed Consolidating Financial Information (Statements Of Cash Flows) (Details) - USD ($) $ in Millions	1 Months Ended	6 Months Ended
	Apr. 30, 2016	Jun. 30, 2016	Jun. 30, 2015
Cash flows from operating activities		$ 193.0	$ 211.1
Cash flows from investing activities:
Purchases of property, plant and equipment		(76.2)	(83.5)
Investment in unconsolidated affiliates		(5.5)	(28.0)
Net proceeds from sale of assets	$ 945.0	942.0	2.1
Proceeds from Equity Method Investment, Dividends or Distributions, Return of Capital		5.5	1.0
Net cash used in investing activities		865.8	(108.4)
Cash flows from financing activities:
Proceeds from the issuance of long-term debt		1,078.8	2,154.6
Principal payments on long-term debt		(1,987.7)	(2,030.6)
Payments on capital leases		(0.9)	(1.2)
Payments for debt-related deferred costs		(3.3)	(11.7)
Distributions to partners		(137.0)	(51.5)
Distributions paid to non-controlling partners		(7.6)	(152.4)
Taxes paid for unit-based compensation vesting		(0.6)	(3.7)
Other		(0.1)	(0.1)
Net cash provided by (used in) financing activities		(1,058.4)	(110.2)
Net change in cash		0.4	(7.5)
Cash at beginning of period		0.5
Cash at end of period		0.9	1.3
Eliminations
Cash flows from operating activities		0.0	0.0
Cash flows from investing activities:
Purchases of property, plant and equipment		0.0	0.0
Investment in unconsolidated affiliates		0.0	0.0
Net proceeds from sale of assets		0.0	0.0
Proceeds from Equity Method Investment, Dividends or Distributions, Return of Capital		0.0	0.0
Capital contributions to consolidated affiliates		(2.8)	24.6
Net cash used in investing activities		(2.8)	24.6
Cash flows from financing activities:
Proceeds from the issuance of long-term debt		0.0	0.0
Principal payments on long-term debt		0.0	0.0
Payments on capital leases		0.0	0.0
Payments for debt-related deferred costs		0.0	0.0
Early Repayment of Senior Debt			0.0
Distributions to partners		0.0	0.0
Distributions paid to non-controlling partners		2.8	(24.6)
Taxes paid for unit-based compensation vesting		0.0	0.0
Change in intercompany balances		0.0	0.0
Other			0.0
Net cash provided by (used in) financing activities		2.8	(24.6)
Net change in cash		0.0	0.0
Cash at beginning of period		0.0	0.0
Cash at end of period		0.0	0.0
Parent Company, Crestwood Midstream Partners, LP | Reportable Legal Entities
Cash flows from operating activities		(110.9)	(89.1)
Cash flows from investing activities:
Purchases of property, plant and equipment		(1.0)	(0.4)
Investment in unconsolidated affiliates		0.0	0.0
Net proceeds from sale of assets		0.0	0.0
Proceeds from Equity Method Investment, Dividends or Distributions, Return of Capital		0.0	0.0
Capital contributions to consolidated affiliates		2.8	(24.6)
Net cash used in investing activities		1.8	(25.0)
Cash flows from financing activities:
Proceeds from the issuance of long-term debt		1,078.8	1,865.1
Principal payments on long-term debt		(1,986.8)	(1,713.2)
Payments on capital leases		0.0	(0.9)
Payments for debt-related deferred costs		(3.3)	(11.7)
Early Repayment of Senior Debt			(13.6)
Distributions to partners		(140.6)	(221.4)
Distributions paid to non-controlling partners		0.0	0.0
Taxes paid for unit-based compensation vesting		0.0	0.0
Change in intercompany balances		1,161.1	210.0
Other			(0.2)
Net cash provided by (used in) financing activities		109.2	114.1
Net change in cash		0.1	0.0
Cash at beginning of period		0.1	0.0
Cash at end of period		0.2	0.0
Guarantor Subsidiaries | Reportable Legal Entities
Cash flows from operating activities		296.5	286.6
Cash flows from investing activities:
Purchases of property, plant and equipment		(75.2)	(83.1)
Investment in unconsolidated affiliates		0.0	0.0
Net proceeds from sale of assets		942.0	2.1
Proceeds from Equity Method Investment, Dividends or Distributions, Return of Capital		0.0	0.0
Capital contributions to consolidated affiliates		0.0	0.0
Net cash used in investing activities		866.8	(81.0)
Cash flows from financing activities:
Proceeds from the issuance of long-term debt		0.0	0.0
Principal payments on long-term debt		(0.7)	0.0
Payments on capital leases		(0.9)	(0.3)
Payments for debt-related deferred costs		0.0	0.0
Early Repayment of Senior Debt			0.0
Distributions to partners		0.0	0.0
Distributions paid to non-controlling partners		0.0	0.0
Taxes paid for unit-based compensation vesting		(0.6)	(2.1)
Change in intercompany balances		(1,161.1)	(210.0)
Other			0.0
Net cash provided by (used in) financing activities		(1,163.3)	(212.4)
Net change in cash		0.0	(6.8)
Cash at beginning of period		0.0	7.6
Cash at end of period		0.0	0.8
Non-Guarantor Subsidiaries | Reportable Legal Entities
Cash flows from operating activities		10.4	6.0
Cash flows from investing activities:
Purchases of property, plant and equipment		0.0	0.0
Investment in unconsolidated affiliates		(5.5)	(27.8)
Net proceeds from sale of assets		0.0	0.0
Proceeds from Equity Method Investment, Dividends or Distributions, Return of Capital		5.5	1.0
Capital contributions to consolidated affiliates		0.0	0.0
Net cash used in investing activities		0.0	(26.8)
Cash flows from financing activities:
Proceeds from the issuance of long-term debt		0.0	0.0
Principal payments on long-term debt		0.0	0.0
Payments on capital leases		0.0	0.0
Payments for debt-related deferred costs		0.0	0.0
Early Repayment of Senior Debt			0.0
Distributions to partners		(7.6)	(3.8)
Distributions paid to non-controlling partners		(2.8)	24.6
Taxes paid for unit-based compensation vesting		0.0	0.0
Change in intercompany balances		0.0	0.0
Other			0.0
Net cash provided by (used in) financing activities		(10.4)	20.8
Net change in cash		0.0	0.0
Cash at beginning of period		0.0	0.0
Cash at end of period		0.0	0.0
Crestwood Midstream Partners LP
Cash flows from operating activities		196.0	203.5
Cash flows from investing activities:
Purchases of property, plant and equipment		(76.2)	(83.5)
Investment in unconsolidated affiliates		(5.5)	(27.8)
Net proceeds from sale of assets		942.0	2.1
Proceeds from Equity Method Investment, Dividends or Distributions, Return of Capital		5.5	1.0
Capital contributions to consolidated affiliates		0.0	0.0
Net cash used in investing activities		865.8	(108.2)
Cash flows from financing activities:
Proceeds from the issuance of long-term debt		1,078.8	1,865.1
Principal payments on long-term debt		(1,987.5)	(1,713.2)
Payments on capital leases		(0.9)	(1.2)
Payments for debt-related deferred costs		(3.3)	(11.7)
Early Repayment of Senior Debt		0.0	(13.6)
Distributions to partners		(148.2)	(225.2)
Distributions paid to non-controlling partners		0.0	0.0
Taxes paid for unit-based compensation vesting		(0.6)	(2.1)
Change in intercompany balances		0.0	0.0
Other		0.0	(0.2)
Net cash provided by (used in) financing activities		(1,061.7)	(102.1)
Net change in cash		0.1	(6.8)
Cash at beginning of period		0.1	7.6
Cash at end of period		$ 0.2	$ 0.8