Supplemental Information Relating to Oil and Natural Gas Producing Activities (Unaudited) Supplemental Information Relating to Oil and Natural Gas Producing Activities (Unaudited) (Tables)

12 Months Ended

Sep. 30, 2014

Cost Incurred in Oil and Gas Property Acquisition, Exploration, and Development Activities Disclosure

Presented below are costs incurred in oil and natural gas property acquisition, exploration and development activities (in millions, except per unit amounts):



	Fiscal 2014		Period from inception to September 30, 2013
Proved property acquisition costs	$	—	$	569.5
Unproved property acquisition costs	—		53.9
Total property acquisition costs	—		623.4
Development	11.4		11.8
Lease acquisitions and other	0.2		—
Capitalized asset retirement costs	0.1		0.1
Depletion per Boe	$	8.68	$	10.00
Depletion per Mcfe	$	1.45	$	1.67

Schedule of Proved Developed and Undeveloped Oil and Gas Reserve Quantities



	Oil (Mbbls)		Natural Gas (Mmcf)		Natural Gas Liquids (Mbbls)		Natural Gas Equivalent (Mmcfe)
Inception
Purchase of reserves in place (1)	3,940		331,592		7,353		399,350
Discoveries and extensions (2)	188		4,416		753		10,062
Revisions of previous estimates:
Changes in price	(125	)	13,116		(135	)	11,556
Other factors (3)	(296	)	(12,136	)	(1,941	)	(25,558	)
Production	(283	)	(14,570	)	(300	)	(18,068	)
September 30, 2013	3,424		322,418		5,730		377,342
Discoveries and extensions (2)	112		839		173		2,549
Revisions of previous estimates:
Changes in price	233		20,815		496		25,189
Other factors (4)	335		(13,750	)	342		(9,688	)
Production	(414	)	(20,882	)	(521	)	(26,492	)
September 30, 2014	3,690		309,440		6,220		368,900


(1)	Purchases of reserves in place include the initial contribution of conventional assets from EXCO as of February 14, 2013, and the acquisition of shallow Cotton Valley assets from an affiliate of BG Group as of March 5, 2013.


(2)	New discoveries and extensions were a result of Compass’ development in the Permian basin for both Fiscal 2014 and the period from inception to September 30, 2013.

(3)

Revisions of previous estimates due to other factors were primarily due to downward adjustments in the Permian basin of 18.1 Bcfe as a result of recent performance and modifications to Compass’ development plans which extended the development beyond a five-year horizon. In addition, revisions of previous estimates due to other factors in the East Texas/North Louisiana region were 7.5 Bcfe primarily due to performance.


(4)	Revisions of previous estimates due to other factors were primarily due to downward adjustments in the East Texas/North Louisiana region of 11.5 Bcfe primarily due to recent performance.

Estimated Quantities of Proved Developed and Undeveloped Reserves



	Oil (Mbbls)	Natural Gas (Mmcf)	Natural Gas Liquids (Mbbls)	Mmcfe
Proved developed:
September 30, 2014	3,356	304,628	5,145	355,634
September 30, 2013	3,107	317,748	4,799	365,185
Proved undeveloped:
September 30, 2014	334	4,812	1,075	13,266
September 30, 2013	317	4,670	931	12,157

Standardized Measure of Discounted Future Cash Flows Relating to Proved Reserves Disclosure



	September 30,
	2014		2013
Future cash inflows	$	1,895.2	$	1,638.5
Future production costs	914.9		923.7
Future development costs	164.4		156.0
Future income taxes	136.2		39.3
Future net cash flows	679.7		519.5
Discount of future net cash flows at 10% per annum	333.9		217.2
Standardized measure of discounted future net cash flows	$	345.8	$	302.3

Schedule of Changes in Standardized Measure of Discounted Future Net Cash Flows

The following are the principal sources of change in the Standardized Measure:



	Fiscal 2014			Period from inception to September 30, 2013
Sales and transfers of oil and natural gas produced	$	(77.4	)	$	(46.2	)
Net changes in prices and production costs	141.8			39.2
Extensions and discoveries, net of future development and production costs	3.5			8.1
Development costs during the period	10.0			7.4
Changes in estimated future development costs	(12.0		)	20.2
Revisions of previous quantity estimates	24.2			(50.2		)
Purchase of reserves in place	—			300.6
Accretion of discount before income taxes	32.3			16.1
Changes in timing and other	(34.3		)	27.9
Net change in income taxes	(44.6		)	(20.8		)
Net change	$	43.5		$	302.3

Schedule of Capitalized Costs of Unproved Properties Excluded from Amortization

The following table summarizes the categories of costs comprising the amount of unproved properties not subject to amortization by the period in which such costs were incurred. There are no individually significant properties or significant development projects included in costs not being amortized. The majority of the evaluation activities are expected to be completed within one to four years.



	Total		Fiscal 2014		Period from inception to September 30, 2013
Property acquisition costs	$	18.9	$	—	$	18.9
Capitalized interest	1.3		0.7		0.6
Total	$	20.2	$	0.7	$	19.5

- Definition

Tabular disclosure of the aggregate of costs (whether the costs are capitalized or charged to expense at the time they are incurred ) incurred for the year in oil and gas property acquisition, exploration and development activities.

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- Definition

Tabular disclosure of the net quantities of an enterprise's interests in proved developed and undeveloped reserves of (a) crude oil (including condensate and natural gas liquids), (b) natural gas (including coal bed methane), (c) synthetic oil, (d) synthetic gas, and (e) other nonrenewable natural resources that are intended to be upgraded during the period as of the beginning of the period, changes in quantities during the period, and as of the end of the period.

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- Definition

Tabular disclosure of the future net cash flows relating to proved oil and gas reserves and oil and gas subject to purchase under long-term agreements in which the enterprise participates in the operation of the properties on which the oil and gas is located or otherwise serves as the producer. This information is presented in aggregate and for each geographic area for which reserve quantities are disclosed.

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