CORRESP 1 filename1.htm

CORRESP

November 19, 2014

Mr. H. Roger Schwall, Assistant Director

Division of Corporation Finance

U.S. Securities and Exchange Commission

100 F Street, N.E.

Washington, D.C. 20549-3628

Re: SandRidge Energy, Inc.

File No. 001-33784

Dear Mr. Schwall,

SandRidge Energy, Inc. (the “Company” or “SandRidge”) hereby submits this letter as a follow up to its September 26, 2014 letter in response to the letter (the “August 15 Letter”) of the staff (the “Staff”) of the U.S. Securities and Exchange Commission (the “Commission”), sent via email on August 15, 2014, which addresses subjects that have been the subject of comment letters and an email previously sent by the Staff (on July 30, 2013; November 13, 2013; February 4, 2014; and June 3, 2014) and responded to by the Company (on August 21, 2013; December 13, 2013; February 19, 2014; and August 19, 2014).

Set forth below in italics is the text of Comment 2 contained in the August 15 Letter, followed by our response thereto. Capitalized terms used but not otherwise defined herein have the respective meanings ascribed to them in the 2012 Form 10-K.

Comment 2

Note 12 - Construction Contracts, page F-34

2. We have read your response to prior comment one, setting forth your views on the accounting for both the annual, and end-of-contract CO2 delivery shortfall liabilities, and understand that while you believe FASB ASC 450-20 is applicable, you have not accrued a liability for the end-of-contract penalty because you do not yet consider payment to be probable and estimable. However, we also note that you recorded a liability for the 2013 annual CO2 delivery shortfall on December 31, 2013, even though the amount appears to have been estimable in an earlier period of time and possibly at the beginning of 2013. For example, you disclose on pages 6, 78 and F-42 of your 2012 Form 10-K that “the Company expects to accrue between $29.5 million and $36.0 million at December 31, 2013,” due to the penalty provisions of the treating agreement.

Mr. H. Roger Schwall

U.S. Securities and Exchange Commission

Page 2

We understand that your annual delivery requirements would be assessed on a calendar year basis under your agreement in applying FASB 450-20. Accordingly, you should recognize the probable loss each fiscal quarter once it becomes reasonably estimable, i.e. when you expect an annual shortfall to occur and require a penalty payment on January 1 of the following calendar year, as a liability pursuant to FASB ASC 450-20-25-1 and 25- 2. A similar approach should be applied to the end-of contract penalty provisions.

Please revise your financial statements accordingly; if you believe the effects would not be material and prefer to limit compliance to future filings, please submit the analysis underlying your view. In either case, please revise your disclosures under this heading and MD&A where indicated and appropriate, to include the following information.

• The cumulative under-delivered quantity of CO₂ at each balance sheet date, the amount of the possible end-of-contract penalty related to this quantity, and the extent to which this has been accrued each period based on your probability assessments.

• The annual penalty that will arise based on current period under-deliveries unless over-deliveries are made during the remainder of the year, and the extent to which this has been accrued each period based on your probability assessments.

• Any constraints on your ability to over-deliver CO₂ in future years to offset the cumulative under-deliveries to date, including a discussion of plant capacity, and the manner by which this is shared with the counterparty.

• Any reasonably possible future delivery scenarios having material implications should be addressed in MD&A (e.g., the extent to which you are expecting delivery shortfalls to continue should be addressed if it is reasonably possible that future over-deliveries will be materially insufficient to offset these amounts).

• Salient details of the provisions which govern your ability to reduce liquidating damages and to terminate the contract early, including the amounts you would need to pay, the manner in which these are calculated at any given date, and your assessment of any reasonably possible scenarios evoking these provisions.

• Clarify the meaning of the language “net of any accrued annual shortfalls” that is used on page 31 of your June 30, 2014 Form 10-Q in discussing the remaining quantities to be delivered under your contract.

• The annual and end-of-contract penalty per Bcf amounts should accompany any related discussion of the CO2 delivery shortfalls.

Response

Background

The Company believes it would be helpful to provide additional clarity about its analysis at the inception of the treating agreement regarding the appropriate accounting for the annual shortfall penalty. In that regard, the Company notes that there is no single comprehensive standard addressing the accounting for expected losses on executory contracts except when an arrangement is within the scope of certain industry-specific and transaction-specific guidance that specifically provides for the accrual of losses, such as the following:

Mr. H. Roger Schwall

U.S. Securities and Exchange Commission

Page 3

• A firm purchase commitment for goods or inventory under ASC 330 – Inventory

• Construction or production-type contracts within the scope of ASC 605-35 – Revenue Recognition – Construction-Type and Production-Type Contracts

• An operating lease that is subleased subject to ASC 840, including ASC 840-20-25-15 and ASC 840-30-35-13, or ASC 420

• Certain executory contracts subject to ASC 420 – Exit or Disposal Cost Obligations

• An insurance contract with a premium deficiency subject to ASC 944-60

• Certain derivative contracts within the scope of ASC 815 – Derivatives and Hedging

• Arrangements accounted for pursuant to ASC 985-605 – Software – Revenue Recognition.

Accordingly, we evaluated whether a loss should be recognized under ASC 420. ASC 420-10-30-7 through 30-9 requires the recognition of a liability for costs that will continue to be incurred under a contract for its remaining term without economic benefit to the entity at its cease-use date. However, since the commencement of the Century Plant treating agreement (which is an executory contract) the Company has consistently utilized a part of the Century Plant’s processing capacity. Therefore, given that the Company continues to utilize the Century Plant and has not terminated the contract or agreed to a cease-use date, it would not be appropriate under this guidance to record a liability that contemplated future annual periods. Furthermore, while the Emerging Issues Task Force (“EITF”) of the Financial Accounting Standards Board discussed loss recognition for all other firmly committed executory contracts from the perspective of the buyer in EITF Issue No. 99-14, “Recognition by a Purchaser of Losses on Firmly Committed Executory Contracts”, the EITF did not reach a consensus on the issue. Accordingly, there is no current authoritative accounting guidance that would support the accelerated recognition of future periodic costs attributable to a firmly committed executory contract unless that contract has been terminated.

Due to the lack of specific guidance with respect to the accounting for executory contracts, the Company determined the method of accounting for CO₂ delivery shortfalls attributable to discrete annual performance periods within the Century Plant treating agreement to be one based upon the definition of a liability. Paragraph 35 of FASB Concepts Statement No. 6, Elements of Financial Statements, defines a liability as “…probable future sacrifices of economic benefits arising from present obligations of a particular entity to transfer assets or provide services to other entities in the future as a result of past transactions or events.” Paragraph 36 provides further discussion of the characteristics of a liability, stating that “A liability has three essential characteristics: (a) it embodies a present duty or responsibility to one or more other entities that entails settlement by probable future transfer or use of assets at a specified or determinable date, on occurrence of a specified event, or on demand, (b) the duty or responsibility obligates a particular entity, leaving it little or no discretion to avoid the future sacrifice, and (c) the transaction or other event obligating the entity has already happened.” Because the definition of a liability indicates that the probable sacrifice of economic benefits in the future must have resulted from past transactions or events and the annual shortfall penalty, calculated in accordance with the terms of the Century Plant treating agreement, is based upon CO₂ deliveries made within discrete annual performance periods, the Company believed the accrual of a liability

Mr. H. Roger Schwall

U.S. Securities and Exchange Commission

Page 4

for an annual delivery shortfall under the agreement would not be recognized until the end of the year because lower CO₂ volumes delivered in any day (or month or quarter) within the annual period could be offset by higher or adequate CO₂ volumes delivered in another day (or month or quarter) within the same annual period. Therefore, the Company believed that accrual at the end of the period when the penalty could be accurately calculated was acceptable in accordance with available guidance.

Notwithstanding the earlier determination that its method of accounting for the Century Plant treating agreement was acceptable, as a result of discussions with the Staff, the Company has concluded that an alternative approach with respect to this specific contract would be to review the annual shortfall penalty on a quarterly basis as a loss contingency under the guidance of ASC 450-20, consistent with the analysis of the end-of-contract penalties, and to apply the guidance in ASC 450-20-25-2 for purposes of its quarterly financial statements. Under the guidance of ASC 450-20-25-2, as natural gas is delivered and processed over each quarterly period, a portion of the under delivery penalty will potentially be incurred for which the final outcome will not be determined until all deliveries and processing for the annual period have occurred or failed to occur. Therefore, in accordance with ASC 450-20-25-2, at the end of each quarterly period, the Company should assess whether it is probable that it will be obligated to pay any annual shortfall penalty attributable to its performance under the contract during the portion of the annual performance period completed thus far. This method of recording only probable losses attributable to the portion of the annual period completed thus far is consistent with the concepts noted within ASC 450-20-25-2, which indicate that even reasonably estimable losses shall not be accrued if it is not probable that a liability has been incurred at the date of the financial statements because those losses relate to a future period rather than the current or a prior period. Additionally, the referenced guidance states that the attribution of a loss to events or activities of the current or prior periods is an element of liability incurrence.

Annual Shortfall Penalty

In accordance with the guidance described above under ASC 450-20, the Company has performed for each applicable quarterly period of 2012, 2013 and 2014 an analysis to determine (i) an estimated delivery shortfall attributable to each period (ii) the probability that the Company will be required to pay a $0.25 per Mcf annual under delivery penalty attributable to these calculated periodic delivery shortfalls and (iii) if probable, the proper expense/loss to be accrued. Results of this analysis are presented below. The Company intends to apply the same analysis to all future quarterly periods during the remaining term of the treating agreement.

(i) Estimated Period Shortfall

This volume is determined at the end of each period based upon a comparison of the average daily quantity of CO₂ delivered to date during the current annual performance period and the average daily CO₂ deliveries necessary to meet the delivery requirement for the current annual performance period (“average daily requirement”). Calculated: (average daily requirement less actual average daily year-to-date CO₂ deliveries) multiplied by the number of days elapsed in the current annual performance period.

Mr. H. Roger Schwall

U.S. Securities and Exchange Commission

Page 5

(ii) Probability

In order to determine whether or not it is probable that the Company will be required to pay a $0.25 per Mcf annual under delivery fee attributable to shortfall volumes calculated in (i) above, an analysis of total CO₂ deliveries the Company expects to make during the remainder of the annual period is performed, subject to available processing capacity for the remainder of the annual performance period. This analysis considers (a) deliveries expected from currently producing wells, as well as (b) the Company’s current intent with respect to its operating activities for the remainder of the annual performance period (e.g. whether it intends to resume drilling in the WTO as a result of changes in oil and/or natural gas prices during the period) and (c) the Company’s current intent or lack thereof to deliver CO₂ under the agreement via purchases from third party producers of CO₂ or natural gas for processing at the Century Plant.

(iii) Accrual

If, based upon the analysis performed in (ii), the Company determines that it is probable that it will pay a $0.25 per Mcf penalty attributable to all or a portion of the shortfall volumes determined in (i), such penalty shall be accrued as of the current period end.

Results of the above analysis for each annual period are as follows:

2012

Estimated Period Shortfall

As the Century Plant was placed into service on September 1, 2012, the annual requirements under the contract became effective at that time, with the 2012 annual requirement included in the terms of the agreement adjusted pro rata for the four-month period then remaining in 2012. The following table presents the estimated penalty attributable to the applicable periods using the above analysis as of each quarter end (dollars in thousands, except penalty per Mcf):

		Q3 2012				Q4 2012
		Estimated Period Expense				Actual
Average daily required MMCF			354.934
Average daily delivered MMCF			81.425
Average daily required less delivered MMCF			273.509
YTD Days in Period			30
Penalty per MCF		$	0.25
Estimated Period Shortfall		$	2,051
YTD estimate		$	2,051			$	8,481
QTD estimate		$	2,051			$	6,430

Mr. H. Roger Schwall

U.S. Securities and Exchange Commission

Page 6

Probability and Estimated Accrual

At the end of each quarter, the Company’s analysis indicated an excess of the average daily requirement in comparison to the average daily deliveries and, therefore, indicated a delivery shortfall attributable to that quarter. At September 30, 2012, the Company intended to continue to produce and deliver natural gas from all active wells in the WTO for the remainder of the annual performance period, but its drilling plan at that time did not include plans to drill in the WTO nor did the Company intend to purchase CO₂ or unprocessed natural gas from other producers for delivery and processing at the Century Plant. Based on an analysis of CO₂ volumes estimated to be delivered from production of the active WTO wells during the remainder of 2012, estimated CO₂ deliveries for the 2012 performance period were not expected to be sufficient to overcome the volume shortfall attributable to the interim period ended September 30, 2012. Therefore, the Company’s analysis indicates that payment of an annual penalty was probable at that time, with approximately $2.1 million attributable to the third quarter volume shortfall. The actual annual penalty expense attributable to the total 2012 annual shortfall of $8.5 million was recorded in the fourth quarter of 2012 and was, therefore, fully accrued in the statement of operations for the year ended December 31, 2012 included in the Form 10-K for 2012.

2013

Estimated Period Expense/Loss

The following table presents the estimated penalty attributable to each period in 2013 as determined using the above analysis as of each quarter end (dollars in thousands, except penalty per Mcf):

		Q1 2013				Q2 2013				Q3 2013				Q4 2013
		Estimated Period Expense				Estimated Period Expense				Estimated Period Expense				Actual
Average daily required MMCF			424.931				424.931				424.931
Average daily delivered MMCF			71.325				70.725				69.148
Average daily required less delivered MMCF			353.606				354.206				355.783
YTD Days in period			90				181				273
Penalty per MCF		$	0.25			$	0.25			$	0.25
Estimated Period Shortfall		$	7,956			$	16,028			$	24,282
YTD accrual		$	7,956			$	16,028			$	24,282			$	32,675
QTD accrual		$	7,956			$	8,072			$	8,254			$	8,393

Mr. H. Roger Schwall

U.S. Securities and Exchange Commission

Page 7

Probability and Estimated Accrual

At the end of each quarter of 2013, the analysis indicated an excess of the average daily requirement in comparison to the average daily deliveries and, therefore, indicated a delivery shortfall attributable to each quarterly period of 2013. At the end of each quarter of 2013, the Company intended to continue to produce and deliver natural gas from all active wells in the WTO for the remainder of the current annual period, but its drilling plan at that time did not include plans to drill in the WTO nor did the Company intend to purchase CO₂ or unprocessed natural gas from other producers for delivery and processing at the Century Plant. Therefore, based on expected deliveries for the remainder of the annual performance period, the analysis indicated that a payment was probable for each of the quarterly periods, with amounts shown above in the row labeled “QTD accrual” attributable to the quarterly periods’ volume shortfalls. The actual annual penalty expense attributable to the total 2013 annual shortfall of $32.7 million was recorded in the fourth quarter of 2013 and was, therefore, fully accrued in the statement of operations for the year ended December 31, 2013 included in the Form 10-K for 2013. See Exhibit A for the assessment performed by Management for each quarter end.

2014

Estimated Period Expense/Loss

The following table presents the estimated penalty attributable to the first and second quarters of 2014 as determined using the above analysis as of each quarter end (dollars in thousands, except penalty per Mcf):

		Q1 2014				Q2 2014
		Estimated Period Expense				Estimated Period Expense
Average daily required MMCF			428.679				428.679
Average daily delivered MMCF			58.846				57.930
Average daily required less delivered			369.833				370.749
YTD Days in period			90				181
Penalty per MCF		$	0.25			$	0.25
Estimated Period Shortfall		$	8,321			$	16,776
YTD accrual		$	8,321			$	16,776
QTD accrual		$	8,321			$	8,455

Probability and Estimated Accrual

At the end of each of the first and second quarters of 2014, the analysis indicated an excess of the average daily requirement in comparison to the average daily deliveries and, therefore, indicated a delivery shortfall attributable to each of the quarters. At the end of each quarter, the Company intended to continue to produce and deliver natural gas from all active wells in the WTO for the remainder of the current annual period, but its drilling plan at that time did not include plans to drill in the WTO nor did the Company intend to purchase CO₂ or unprocessed natural gas for delivery and processing at the Century Plant. Therefore, based on expected deliveries for the remainder of the annual performance period, the analysis indicated that a payment was probable for each of the quarterly periods, with amounts shown above in the row labeled “QTD accrual” attributable to the quarterly periods’ volume shortfalls. See Exhibit A for the assessment performed by Management for each quarter end.

Mr. H. Roger Schwall

U.S. Securities and Exchange Commission

Page 8

All Periods - End-Of-Contract Penalty

A similar approach to the method described above was applied to determine if any end-of-contract penalties ($0.70 per Mcf) should be accrued as of the end of any of the interim periods in the analysis. As discussed in previous comment letter responses, the Company is not currently able to determine whether payment of such end-of-contract penalties attributable to estimated delivery shortfalls occurring thus far are probable due to the sensitivity of drilling activity to market prices for natural gas, provisions within the treating agreement allowing annual delivery shortfalls to be recouped in subsequent periods within the term of the agreement and the length of time remaining in the term of the treating agreement. In that regard, the Company’s most recent analysis indicates that it could shut in current production for more than a decade before processing capacity became a limiting factor. Therefore, the end-of-contract penalty attributable to delivery shortfalls incurred to date is not probable and not reasonably estimable for any periods included in the assessment. The Company will continue to perform an analysis each quarter to determine whether payment of end-of-contract penalties is probable with respect to delivery shortfalls incurred in current and prior periods. This analysis will include an assessment of (i) the Company’s planned future operational activity as well as (ii) whether or not adequate daily available processing capacity exists for the remaining term of the contract in order to allow the Company to meet the total contract volume requirement.

Financial Statement Impact Analysis

An analysis of the impact of the estimated unrecorded under delivery penalty for each quarterly and year-to-date period is as follows:

		QTD September 30, 2012																YTD September 30, 2012																QTD December 31, 2012
(in thousands)		As Reported				As Revised				$ Change				% Change				As Reported				As Revised				$ Change				% Change				As Reported				As Revised				$ Change				% Change
Production expense			137,033				139,084				(2,051	)			-1	%			342,824				344,875				(2,051	)			-1	%			134,330				132,279				2,051				2	%
Total expense			608,669				610,720				(2,051	)			0	%			857,981				860,032				(2,051	)			0	%			1,547,788				1,545,737				2,051				0	%
(Loss) income before taxes			(159,579	)			(161,630	)			2,051				-1	%			440,727				438,676				2,051				0	%			(294,518	)			(292,467	)			(2,051	)			1	%
Net (loss) income			(159,752	)			(161,803	)			2,051				-1	%			541,100				539,049				2,051				0	%			(294,530	)			(292,479	)			(2,051	)			1	%
Adjusted net income			29,613				27,562				2,051				7	%			87,566				85,515				2,051				2	%			35,287				37,338				(2,051	)			-6	%
Adjusted EBITDA			297,490				295,439				2,051				1	%			751,615				749,564				2,051				0	%			318,215				320,266				(2,051	)			-1	%

Mr. H. Roger Schwall

U.S. Securities and Exchange Commission

Page 9

		QTD March 31, 2013																QTD June 30, 2013																YTD June 30, 2013
(in thousands)		As Reported				As Revised				$ Change				% Change				As Reported				As Revised				$ Change				% Change				As Reported				As Revised				$ Change				% Change
Production expense			132,501				140,457				(7,956	)			-6	%			116,811				124,883				(8,072	)			-7	%			249,312				265,340				(16,028	)			-6	%
Total expense			871,216				879,172				(7,956	)			-1	%			426,529				434,601				(8,072	)			-2	%			1,297,745				1,313,773				(16,028	)			-1	%
(Loss) income before taxes			(526,830	)			(534,786	)			7,956				-2	%			25,193				17,121				8,072				32	%			(501,637	)			(517,665	)			16,028				-3	%
Net (loss) income			(531,259	)			(539,215	)			7,956				-1	%			24,685				16,613				8,072				33	%			(506,574	)			(522,602	)			16,028				-3	%
Adjusted net income			2,031				(5,925	)			7,956				392	%			44,634				36,562				8,072				18	%			49,894				33,866				16,028				32	%
Adjusted EBITDA			269,853				261,897				7,956				3	%			267,560				259,488				8,072				3	%			537,413				521,385				16,028				3	%
		QTD September 30, 2013																YTD September 30, 2013																QTD December 31, 2013
(in thousands)		As Reported				As Revised				$ Change				% Change				As Reported				As Revised				$ Change				% Change				As Reported				As Revised				$ Change				% Change
Production expense			116,317				124,571				(8,254	)			-7	%			365,629				389,911				(24,282	)			-7	%			150,798				126,516				24,282				16	%
Total expense			487,515				495,769				(8,254	)			-2	%			1,785,260				1,809,542				(24,282	)			-1	%			367,129				342,847				24,282				7	%
(Loss) income before taxes			(54,639	)			(62,893	)			8,254				-15	%			(556,276	)			(580,558	)			24,282				-4	%			47,481				71,763				(24,282	)			-51	%
Net (loss) income			(57,002	)			(65,256	)			8,254				-14	%			(563,576	)			(587,858	)			24,282				-4	%			49,097				73,379				(24,282	)			-49	%
Adjusted net income			40,364				32,110				8,254				20	%			89,287				65,005				24,282				27	%			14,888				39,170				(24,282	)			-163	%
Adjusted EBITDA			252,470				244,216				8,254				3	%			790,215				765,933				24,282				3	%			229,115				253,397				(24,282	)			-11	%
		QTD March 31, 2014																QTD June 30, 2014																YTD June 30, 2014
(in thousands)		As Reported				As Revised				$ Change				% Change				As Reported				As Revised				$ Change				% Change				As Reported				As Revised				$ Change				% Change
Production expense			98,535				106,856				(8,321	)			-8	%			58,498				66,953				(8,455	)			-14	%			157,033				173,809				(16,776	)			-11	%
Total expense			517,065				525,386				(8,321	)			-2	%			324,180				332,635				(8,455	)			-3	%			841,245				858,021				(16,776	)			-2	%
(Loss) income before taxes			(133,958	)			(142,279	)			8,321				-6	%			(9,991	)			(18,446	)			8,455				-85	%			(143,949	)			(160,725	)			16,776				-12	%
Net (loss) income			(134,085	)			(142,406	)			8,321				-6	%			(8,797	)			(17,252	)			8,455				-96	%			(142,882	)			(159,658	)			16,776				-12	%
Adjusted net income			37,856				29,535				8,321				22	%			34,154				25,699				8,455				25	%			78,084				61,308				16,776				21	%
Adjusted EBITDA			230,394				222,073				8,321				4	%			210,314				201,859				8,455				4	%			440,708				423,932				16,776				4	%

Based on this approach for accounting for the annual shortfall penalty, the Company intends to restate the 2013 quarterly information in the notes to the financial statements in an amended annual report on Form 10-K/A for 2013 to reflect the above annual penalty shortfall attributable to the quarterly periods. In addition, the Company intends to restate the statements of operations for the first and second quarterly periods of 2013 and the first and second quarterly periods of 2014 by filing amended quarterly reports on Form 10-Q/A for each of the first and second quarterly periods of 2014 to reflect the above annual penalty shortfall attributable to the quarterly periods. The Company will restate the statement of operations for the third quarter of 2013 in its Form 10-Q for the third quarter of 2014 to reflect the above annual penalty shortfall attributable to the quarterly periods. Additionally, the Company will revise other related information contained in such filings, including management’s discussion and analysis of financial condition and results of operations, as necessary to provide consistent information for the periods presented. Because the annual penalty expense attributable to the total 2013 shortfall of $32.7 million was recorded in the fourth quarter of 2013, the correction in the quarterly financial statements will not result in a restatement of the statement of operations for the year ended December 31, 2013. Based on the analysis above, the Company concluded that the impact of this approach for accounting for the annual shortfall penalty was not quantitatively or qualitatively material to any results for 2012 and, therefore, concluded that it is not necessary to restate any result for periods in 2012.

Mr. H. Roger Schwall

U.S. Securities and Exchange Commission

Page 10

In addition, in response to the Staff’s comment, the Company intends to include additional disclosures in the footnotes to its financial statements and MD&A in the above amendments as well as the Form 10-Q for the third quarter of 2014 and future filings consistent with the following:

Through December 31, 2013, the Company had delivered to Occidental [    ] Mcf of CO₂, which is [            ] Mcf less than the cumulative minimum annual CO₂ volume requirements for the same period. If such underdelivered volumes are not made up with commensurate overdeliveries in the future, the Company will be obligated to pay Occidental $0.70 per Mcf (approximately $[    ] total) in 2041, which amount has not been accrued by the Company as a liability.

Under certain circumstances, the Company will have the right, beginning in [            ], to reduce future minimum annual CO₂ volume requirements under the agreement by paying Occidental an amount equal to the present value of $0.70 multiplied by such reduced CO₂ volume requirements as designated by the Company. Assuming no future CO₂ deliveries by the Company, this amount would be approximately [$     ] as of [     ], to adjust the future CO₂ volume requirements to zero. The Company also may terminate the treating agreement at any time, which would require a termination payment by the Company to Occidental of an amount equal to (a) the present value of $0.70 multiplied by the remaining CO₂ volumes required to be delivered under the agreement, plus (b) Occidental’s current net book value of the Century Plant.

Based upon the quantity of CO₂ delivered by the Company during the period from January 1, 2014 through September 30, 2014 and estimated quantities the Company expects to deliver during the remainder of 2014, the Company accrued an estimated annual under delivery penalty ($0.25 per Mcf) of approximately $[    ] million for the nine-month period ended September 30, 2014. The Company has not accrued any liability for the $0.70 per Mcf fee (approximately $[    ] million total) that would be due in 2041 if the anticipated shortfall occurs and is not made up in the future as the Company does not believe it is probable.

The Company has first priority on daily available processing capacity for properly nominated and delivered volumes; however, based on cumulative delivered volumes to date, if no further deliveries are made by the Company, beginning in [  *  ] the Century Plant, even if fully utilized, would not have adequate capacity to allow the Company to deliver CO₂ volumes attributable to previously incurred delivery shortfalls at that time.

* As of September 30, 2014, beginning in 2025

Mr. H. Roger Schwall

U.S. Securities and Exchange Commission

Page 11

The Company continues to reassess its previous conclusions regarding the effectiveness of internal control over financial reporting and disclosure controls and procedures as they relate to the accounting under the treating agreement.

Mr. H. Roger Schwall

U.S. Securities and Exchange Commission

Page 12

If you have any questions or require any additional information, please contact Philip T. Warman at 405-429-6136 or Justin P. Byrne at 405-429-5706.

Very truly yours,
SandRidge Energy, Inc.
By:		/s/ Eddie M. LeBlanc III
Name:		Eddie M. LeBlanc III
Title:		Executive Vice President and Chief Financial Officer

Mr. H. Roger Schwall

U.S. Securities and Exchange Commission

Page 13

Exhibit A

Responses From Management and Operations at Period End Concerning the WTO

Current Gas

Enter 3rd Party

NYMEX Price

Allocated Capex

Purchase Raw

Purchase

Shut in

Allocated Capex

Development

Period End

(1)

To WTO Drilling

Gas

CO2

Wells

To Workovers

Agreements

December 31, 2012

$

3.696

none

no

no

no

none

none

March 31, 2013

$

3.427

none

no

no

no

none

none

June 30, 2013

$

4.418

none

no

no

no

none

none

September 30, 2013

$

3.567

none

no

no

no

none

none

December 31, 2013

$

3.818

none

no

no

no

none

none

March 31, 2014

$

4.855

none

no

no

no

none

none

June 30, 2014

$

4.619

none

no

no

no

none

none

(1) This represents only the current price, however the forward strip was utilized in the decision making process.