SandRidge Mississippian Trust I - Quarter Report: 2012 September (Form 10-Q)

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UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

Form 10-Q

(Mark One)

For the quarterly period ended September 30, 2012

OR

For the transition period from              to             

Commission File Number: 001-35122

SANDRIDGE MISSISSIPPIAN TRUST I

(Exact name of registrant as specified in its charter)

Registrant’s telephone number, including area code:

(512) 236-6531

Former name, former address and former fiscal year, if changed since last report: Not applicable

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.    Yes  þ    No   ¨

Indicate by check mark whether the registrant has submitted electronically and posted on its corporate website, if any, every Interactive Data File required to be submitted and posted pursuant to Rule 405 of Regulation S-T during the preceding 12 months (or for such shorter period that the registrant was required to submit and post such files).    Yes  ¨    No   ¨

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.

Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act).    Yes  ¨    No   þ

As of November 6, 2012, 21,000,000 Common Units and 7,000,000 Subordinated Units of Beneficial Interest in SandRidge Mississippian Trust I were outstanding.

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SANDRIDGE MISSISSIPPIAN TRUST I

FORM 10-Q

Quarter Ended September 30, 2012

All references to “we,” “us,” “our,” or the “Trust” refer to SandRidge Mississippian Trust I. References to “SandRidge” refer to SandRidge Energy, Inc., and where the context requires, its subsidiaries. The royalty interests conveyed by SandRidge from its interests in certain properties in the Mississippian formation in Oklahoma and held by the Trust are referred to as the “Royalty Interests.”

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DISCLOSURES REGARDING FORWARD-LOOKING STATEMENTS

This Quarterly Report on Form 10-Q (“Quarterly Report”) includes “forward-looking statements” about the Trust, SandRidge and other matters discussed herein that are subject to risks and uncertainties within the meaning of Section 27A of the Securities Act of 1933, as amended (the “Securities Act”), and Section 21E of the Securities Exchange Act of 1934, as amended (the “Exchange Act”). All statements other than statements of historical fact included in this document, including, without limitation, statements under “Trustee’s Discussion and Analysis of Financial Condition and Results of Operations” in Item 2 of Part I and elsewhere herein regarding the Trust’s or SandRidge’s plans and objectives for future operations, information regarding target distributions and statements regarding the number of development wells to be completed in future periods, are forward-looking statements. Actual outcomes and results may differ materially from those projected. Our forward-looking statements are generally accompanied by words such as “estimate,” “target,” “project,” “predict,” “believe,” “expect,” “anticipate,” “potential,” “could,” “may,” “foresee,” “plan,” “goal,” “should,” “intend” or other words that convey the uncertainty of future events or outcomes. We have based these forward-looking statements on our current expectations and assumptions about future events. These statements are based on certain assumptions made by us in light of our experience and our perception of historical trends, current conditions and expected future developments as well as other factors we believe are appropriate under the circumstances. However, whether actual results and developments will conform with our expectations and predictions is subject to a number of risks and uncertainties, including the risk factors discussed in Item 1A of the Trust’s Annual Report on Form 10-K for the fiscal year ended December 31, 2011 (the “2011 Form 10-K”), which could affect the future results of the energy industry in general, and the Trust and SandRidge in particular, and could cause those results to differ materially from those expressed in such forward-looking statements. The actual results or developments anticipated may not be realized or, even if substantially realized, they may not have the expected consequences to or effects on SandRidge’s business or the Trust’s results. Such statements are not guarantees of future performance and actual results or developments may differ materially from those projected in such forward-looking statements. The Trust undertakes no obligation to publicly update or revise any forward-looking statements.

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PART I. Financial Information

ITEM 1. Financial Statements

SANDRIDGE MISSISSIPPIAN TRUST I

STATEMENTS OF ASSETS AND TRUST CORPUS

(In thousands, except unit data)

The accompanying notes are an integral part of these financial statements.

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SANDRIDGE MISSISSIPPIAN TRUST I

STATEMENTS OF DISTRIBUTABLE INCOME

(In thousands, except unit and per unit data)

The accompanying notes are an integral part of these financial statements.

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SANDRIDGE MISSISSIPPIAN TRUST I

STATEMENTS OF CHANGES IN TRUST CORPUS

(In thousands)

The accompanying notes are an integral part of these financial statements.

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SANDRIDGE MISSISSIPPIAN TRUST I

NOTES TO FINANCIAL STATEMENTS

(Unaudited)

1. Organization of Trust

SandRidge Mississippian Trust I (the “Trust”) is a statutory trust formed on December 30, 2010 under the Delaware Statutory Trust Act pursuant to a trust agreement by and among SandRidge Energy, Inc. (“SandRidge”), as Trustor, The Bank of New York Mellon Trust Company, N.A., as Trustee (the “Trustee”), and The Corporation Trust Company, as Delaware Trustee (the “Delaware Trustee”). The trust agreement was amended and restated by SandRidge, the Trustee and the Delaware Trustee on April 12, 2011. References in this report to the “trust agreement” are to the amended and restated trust agreement.

The Trust was created to acquire and hold Royalty Interests in specified oil and natural gas properties located in the Mississippian formation in Alfalfa, Garfield, Grant, Major and Woods counties in Oklahoma (the “Underlying Properties”). The Royalty Interests were conveyed by SandRidge to the Trust concurrent with the initial public offering of the Trust’s common units in April 2011. As consideration for conveyance of the Royalty Interests, the Trust remitted the proceeds of the offering, along with 3,750,000 Trust common units and 7,000,000 Trust subordinated units, to certain wholly owned subsidiaries of SandRidge. At September 30, 2012, SandRidge owned 1,216,063 Trust common units and 7,000,000 Trust subordinated units.

The Royalty Interests entitle the Trust to receive 90% of the proceeds (after deducting post-production costs and any applicable taxes) from the sale of oil, including natural gas liquids, and natural gas production attributable to SandRidge’s net revenue interest in 36 wells producing at December 31, 2010 and one additional well undergoing completion operations at that time (together, the “Initial Wells”), and 50% of the proceeds (after deducting post-production costs and any applicable taxes) from the sale of oil, including natural gas liquids, and natural gas production attributable to SandRidge’s net revenue interest in 123 development wells to be drilled (the “Trust Development Wells”) within an area of mutual interest (“AMI”) beginning on January 1, 2011, the effective date of the conveyance. Although the Trust was formed on December 30, 2010, conveyance of the Royalty Interests did not occur until April 2011 and no proceeds from the sale of oil and natural gas production were received by the Trust until August 2011.

As specified in the development agreement executed by the Trust with SandRidge (see Note 5), SandRidge is credited for having drilled one full Trust Development Well if the well is drilled and perforated for completion with a minimum perforated length of 2,500 feet in a specified target formation and SandRidge’s net revenue interest in the well is equal to 57.0%. The actual number of wells required to be drilled may increase or decrease in proportion to SandRidge’s net revenue interest and the perforated length of each well. At September 30, 2012, the Trust’s properties consisted of Royalty Interests in (a) the Initial Wells, (b) 89 additional wells (equivalent to approximately 94 Trust Development Wells under the development agreement as described in Note 5) that were drilled and perforated for completion between December 31, 2010 and September 30, 2012, and (c) the equivalent of approximately 29 Trust Development Wells to be drilled within the AMI.

The Trust makes quarterly cash distributions of substantially all of its cash receipts, after deducting amounts for the Trust’s administrative expenses and cash reserves withheld by the Trustee, on or about 60 days following the completion of each quarter. Due to the timing of the payment of production proceeds to the Trust, each distribution covers production from a three-month period consisting of the first two months of the most recently ended quarter and the final month of the quarter preceding it.

The common and subordinated units have identical rights and privileges, except with respect to their rights to receive distributions. The subordinated units, all of which are held by SandRidge, constitute 25% of the Trust units issued and outstanding. The subordinated units are entitled to receive pro rata distributions from the Trust each quarter if and to the extent there is sufficient cash to provide a cash distribution on the common units that is no less than 80% of the target distribution for the corresponding quarter (“Subordination Threshold”). If there is not sufficient cash to fund such a distribution on all of the common units, the distribution to be made with respect to the subordinated units is reduced or eliminated for such quarter in order to make a distribution, to the extent possible, of up to the Subordination Threshold amount on all of the common units. In exchange for agreeing to subordinate a portion of its Trust units, and in order to provide additional financial incentive to SandRidge to satisfy its drilling obligation, SandRidge is entitled to receive incentive distributions equal to 50% of the amount by which the cash available for distribution on all of the Trust units in any quarter exceeds 120% of the target distribution for such quarter (“Incentive Threshold”). At the end of the fourth full calendar quarter following SandRidge’s satisfaction of its drilling obligation with respect to the Trust Development Wells, the subordinated units will automatically convert into common units on a one-for-one basis and SandRidge’s right to receive incentive distributions will terminate. After such time, the common units will no longer have the protection of the Subordination Threshold, and all Trust unitholders will share on a pro rata basis in the Trust’s distributions.

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SANDRIDGE MISSISSIPPIAN TRUST I

NOTES TO FINANCIAL STATEMENTS - CONTINUED

(Unaudited)

2. Basis of Presentation and Summary of Significant Accounting Policies

Basis of Accounting. The financial statements of the Trust differ from financial statements prepared in accordance with accounting principles generally accepted in the United States of America (“GAAP”) as the Trust records revenues when cash is received (rather than when earned) and expenses when paid (rather than when incurred) and may also establish certain cash reserves for contingencies, which would not be accrued in financial statements prepared in accordance with GAAP. This comprehensive basis of accounting other than GAAP corresponds to the accounting permitted for royalty trusts by the Securities and Exchange Commission (“SEC”) as specified by Staff Accounting Bulletin Topic 12:E, Financial Statements of Royalty Trusts. Amortization of investment in royalty interests, calculated on a unit-of-production basis, and any impairments are charged directly to trust corpus. Distributions to unitholders are recorded when declared.

Significant Accounting Policies. Most accounting pronouncements apply to entities whose financial statements are prepared in accordance with GAAP, directing such entities to accrue or defer revenues and expenses in a period other than when such revenues are received or expenses are paid. Because the Trust’s financial statements are prepared on the modified cash basis as described above, most accounting pronouncements are not applicable to the Trust’s financial statements.

The Trust is treated for federal and applicable state income tax purposes as a partnership. For U.S. federal income tax purposes, a partnership is not a taxable entity and incurs no U.S. federal income tax liability. With respect to state taxation, a partnership is typically treated in the same manner as it is for U.S. federal income tax purposes.

Interim Financial Statements. The accompanying unaudited financial statements have been prepared in accordance with the accounting policies stated in the audited financial statements contained in the 2011 Form 10-K and reflect all adjustments that are, in the opinion of the Trustee, necessary to state fairly the information in the Trust’s unaudited interim financial statements. The accompanying statement of assets and trust corpus as of December 31, 2011 has been derived from audited financial statements. The unaudited financial statements should be read in conjunction with the financial statements and notes thereto included in the 2011 Form 10-K.

Risks and Uncertainties. The Trust’s revenue and distributions are substantially dependent upon the prevailing and future prices for oil and natural gas, each of which depends on numerous factors beyond the Trust’s control such as overall oil and natural gas production and inventories in relevant markets, economic conditions, the global political environment, regulatory developments and competition from other energy sources. Oil and natural gas prices historically have been volatile and may be subject to significant fluctuations in the future. The Trust’s derivative arrangements serve to mitigate a portion of the effect of this price volatility. See Note 5 for a discussion of the Trust’s open oil and natural gas commodity derivative contracts.

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SANDRIDGE MISSISSIPPIAN TRUST I

NOTES TO FINANCIAL STATEMENTS - CONTINUED

(Unaudited)

3. Distributions to Unitholders

The Trust makes quarterly cash distributions of substantially all of its cash receipts, after deducting amounts for the Trust’s administrative expenses and cash reserves withheld by the Trustee, on or about 60 days following the completion of each quarter. Other than the first distribution, which covered production for the five-month period from January 1, 2011 to May 31, 2011, distributions cover a three-month period. See Note 6 for discussion of the Trust’s quarterly distribution to be paid in November 2012. A summary of distributions declared and paid to unitholders during 2011 and the nine-month period ended September 30, 2012 is as follows:

4. Loan Commitment

Pursuant to the trust agreement, if at any time the Trust’s cash on hand (including available cash reserves) is not sufficient to pay the Trust’s ordinary course administrative expenses as they become due, SandRidge will loan funds to the Trust necessary to pay such expenses. Any funds loaned by SandRidge pursuant to this commitment will be limited to the payment of current accounts payable or other obligations to trade creditors in connection with obtaining goods or services or the payment of other accrued current liabilities arising in the ordinary course of the Trust’s business, and may not be used to satisfy Trust indebtedness, or to make distributions. If SandRidge loans funds pursuant to this commitment, no further distributions will be made to unitholders (except in respect of any previously determined quarterly cash distribution amount) until such loan is repaid. Any such loan will be on an unsecured basis, and the terms of such loan will be substantially the same as those which would be obtained in an arm’s length transaction between SandRidge and an unaffiliated third party. There was no such loan outstanding with SandRidge at September 30, 2012 or December 31, 2011.

5. Related Party Transactions

Trustee Administrative Fee. Under the terms of the trust agreement, the Trust pays an annual administrative fee of $150,000 to the Trustee, which will be adjusted for inflation by no more than 3% in any year beginning in 2017. During the three and nine-month periods ended September 30, 2012, the Trustee’s administrative fees were equal to approximately $38,000 and $113,000, respectively.

Registration Rights Agreement. The Trust is party to a registration rights agreement pursuant to which the Trust has agreed to register the offering of the Trust units held by SandRidge and certain of its affiliates and permitted transferees upon request by SandRidge. On October 24, 2012, pursuant to the registration rights agreement, the Trust and SandRidge filed a registration statement on Form S-3 registering the offering by SandRidge Exploration and Production, LLC of 528,063 common units. The registration statement was declared effective on November 7, 2012.

Development Agreement. The Trust is party to a development agreement with SandRidge, effective January 1, 2011, that obligates SandRidge to drill, or cause to be drilled, the Trust Development Wells by December 31, 2015. Additionally, SandRidge agreed not to drill and complete, or allow another person within its control to drill and complete, any other well in the AMI other than the Trust Development Wells until SandRidge has fulfilled its drilling obligation.

        A wholly owned subsidiary of SandRidge granted to the Trust a lien (“Drilling Support Lien”) covering its interest in the AMI (except its interest in the Initial Wells) in order to secure the estimated amount of the drilling costs for the Trust’s interests in the undeveloped Underlying Properties. The initial amount recoverable by the Trust pursuant to the Drilling Support Lien could not exceed approximately $166.1 million, subject to adjustment as described below. As SandRidge fulfills its drilling obligation over time, the total amount that may be recovered is proportionately reduced and the Trust Development Wells drilled and perforated for completion are released from the lien. If SandRidge does not fulfill its drilling obligation by December 31, 2015, the Trust may

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SANDRIDGE MISSISSIPPIAN TRUST I

NOTES TO FINANCIAL STATEMENTS - CONTINUED

(Unaudited)

foreclose on any remaining interest in the AMI that is subject to the Drilling Support Lien. Any amounts actually recovered in a foreclosure action would be applied to the completion of SandRidge’s drilling obligation and would not result in a distribution to the Trust’s unitholders. At September 30, 2012, SandRidge had drilled and perforated for completion approximately 94 equivalent Trust Development Wells, and, accordingly, the maximum amount potentially recoverable under the Drilling Support Lien had been reduced to approximately $38.8 million.

Administrative Services Agreement. The Trust is party to an administrative services agreement with SandRidge, effective January 1, 2011, that obligates the Trust to pay SandRidge an annual administrative services fee for accounting, tax preparation, bookkeeping and informational services to be performed by SandRidge on behalf of the Trust. For its services under the administrative services agreement, SandRidge receives an annual fee of $200,000, which is payable in equal quarterly installments and will remain fixed for the life of the Trust. SandRidge is also entitled to receive reimbursement for its out-of-pocket fees, costs and expenses incurred in connection with the provision of any of the services under this agreement. The administrative services agreement will terminate on the earliest to occur of: (i) the date the Trust shall have dissolved and commenced winding up in accordance with the trust agreement, (ii) the date that all of the Royalty Interests have been terminated or are no longer held by the Trust, (iii) pertaining to services to be provided with respect to any Underlying Properties transferred by SandRidge, the date that either SandRidge or the Trustee may designate by delivering 90-days’ prior written notice, provided that SandRidge's drilling obligation has been completed and the transferee of such Underlying Properties assumes responsibility to perform the services in place of SandRidge and (iv) a date mutually agreed to by SandRidge and the Trustee. During the three and nine-month periods ended September 30, 2012, the Trust paid SandRidge’s administrative fees equal to $50,000 and $150,000, respectively.

Derivatives Agreement. The Trust is party to a derivatives agreement with SandRidge, effective April 1, 2011, that provides the Trust with the economic effect of certain oil and natural gas derivative contracts entered into by SandRidge with third parties. The underlying commodity derivative contracts cover volumes of oil and natural gas production through December 31, 2015. Under the derivatives agreement, SandRidge pays the Trust amounts it receives from its counterparties and the Trust pays SandRidge any amounts that SandRidge is required to pay such counterparties. The Trust did not bear any costs related to the establishment of the underlying contracts. The Trust does not have the ability to enter into its own derivative contracts. The commodity derivative contracts underlying the derivatives agreements consist of fixed price swaps and collars, which are described below:

The following tables present, as of September 30, 2012, the notional amount and weighted average fixed price or collar range of the open contracts underlying the derivatives agreement.

Oil – Price Swaps

Natural Gas – Collars

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SANDRIDGE MISSISSIPPIAN TRUST I

NOTES TO FINANCIAL STATEMENTS - CONTINUED

(Unaudited)

6. Subsequent Events

Distribution to Unitholders. On November 1, 2012, the Trust declared a cash distribution of $0.683076 per unit covering production for the three-month period from June 1, 2012 to August 31, 2012 for record holders as of November 14, 2012. The distribution will be paid on or about November 29, 2012. Distributable income for June 1, 2012 to August 31, 2012 was calculated as follows (in thousands, except for unit and per unit amounts):

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ITEM 2. Trustee’s Discussion and Analysis of Financial Condition and Results of Operations

Introduction

The following discussion and analysis is intended to help the reader understand the Trust’s financial condition, results of operations, liquidity and capital resources. This discussion and analysis should be read in conjunction with the Trust’s unaudited financial statements and the accompanying notes included in this Quarterly Report and the Trust’s audited financial statements and the accompanying notes included in the 2011 Form 10-K.

Overview

The Trust is a statutory trust created on December 30, 2010 under the Delaware Statutory Trust Act. The business and affairs of the Trust are managed by the Trustee and, as necessary, the Delaware Trustee. The Trust’s purpose is to hold the Royalty Interests, to distribute to the Trust unitholders cash that the Trust receives in respect of the Royalty Interests and the derivatives agreement (described in Note 5 to the unaudited financial statements contained in Part I, Item 1 of this Quarterly Report) and to perform certain administrative functions in respect of the Royalty Interests and the Trust units. Other than the foregoing activities, the Trust does not conduct any operations or activities. The Trustee has no involvement with, control or authority over, or responsibility for, any aspect of the operations on or relating to the properties in which the Trust has an interest. The Trust derives all or substantially all of its income and cash flow from the Royalty Interests and the derivatives agreement. The Trust is treated as a partnership for federal income tax purposes.

Properties. At September 30, 2012, the Trust’s properties consisted of Royalty Interests in (a) the Initial Wells, (b) 89 additional wells (equivalent to approximately 94 Trust Development Wells under the development agreement as described below) that were drilled and perforated for completion between December 31, 2010 and September 30, 2012, and (c) the equivalent of approximately 29 Trust Development Wells to be drilled within an AMI consisting of approximately 49,700 gross acres (42,000 net acres) in Alfalfa, Garfield, Grant, Major and Woods counties in Oklahoma.

SandRidge is obligated to drill, or cause to be drilled, the Trust Development Wells on or before December 31, 2015. SandRidge is not permitted to drill and complete any well within the AMI for its own account until it has satisfied the drilling obligation to the Trust. SandRidge has granted to the Trust a lien covering its interest in the AMI (except its interest in the Initial Wells) in order to secure the estimated amount of the drilling costs for the Trust’s interests in the undeveloped Underlying Properties, the balance of which is reduced as SandRidge fulfills its drilling obligation under the development agreement. At September 30, 2012, the amount potentially recoverable under the lien was approximately $38.8 million.

The Trust is not responsible for any costs related to the drilling of the Trust Development Wells or any other operating or capital costs related to the Underlying Properties. The following table presents the number of Initial Wells, Trust Development Wells drilled and Trust Development Wells to be drilled as of December 31, 2011 and September 30, 2012.

Distributions. The Trust makes quarterly cash distributions of substantially all of its cash receipts, after deducting amounts for the Trust’s administrative expenses and cash reserves withheld by the Trustee, on or about 60 days following the completion of each quarter. The Trust’s subordinated units are entitled to receive pro rata distributions from the Trust each quarter if and to the extent there is sufficient cash to provide a cash distribution on the common units that is at least equal to the Subordination Threshold. If there is not sufficient cash to fund such a distribution on all of the common units (including the common units SandRidge owns), the distribution to be made with respect to the subordinated units is reduced or eliminated for such quarter in order to make a distribution, to the extent possible, to all of the common units (including the common units held by SandRidge) up to the Subordination Threshold. However, there is no minimum distribution. If the cash available for distribution on all of the Trust units in any quarter exceeds the Incentive Threshold for the corresponding quarter, SandRidge, as holder of the Trust’s subordinated units, is entitled to 50% of the amount by which the cash available for distribution exceeds the Incentive Threshold.

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The following table sets forth the Subordination Threshold and Incentive Threshold for each remaining calendar quarter through the fourth quarter of 2016, as set out in the trust agreement.

Pursuant to Internal Revenue Code Section 1446, withholding tax on income effectively connected to a United States trade or business allocated to foreign partners should be made at the highest marginal rate. Under Section 1441, withholding tax on fixed, determinable, annual, periodic income from United States sources allocated to foreign partners should be made at 30% of gross income unless the rate is reduced by treaty. This is intended to be a qualified notice to nominees and brokers as provided for under Treasury Regulation Section 1.1446-4(b) by the Trust, and while specific relief is not specified for Section 1441 income, this disclosure is intended to suffice. Nominees and brokers should withhold 35% of the distribution made to foreign partners.

Results of Trust Operations

The primary factors affecting the Trust’s revenues and costs are the quantity of oil and natural gas production attributable to the Royalty Interests, the prices received for such production and amounts paid or received as net settlements under the derivatives agreement. Royalty income, post-production expenses, production taxes and derivative settlements are recorded on a cash basis when net revenue distributions are received by the Trust from SandRidge. Although the Trust was formed on December 30, 2010, the conveyance of the Royalty Interests did not occur until April 2011 and no proceeds from the sale of oil and natural gas production were received by the Trust until August 2011. As a result, the Trust did not recognize any income or make any distributions until August 2011. Information regarding the Trust’s production, pricing and costs for the three and nine-month periods ended September 30, 2012 and 2011 is presented below.

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Three Months Ended September 30, 2012 Compared to the Three Months Ended September 30, 2011

Royalty Income. Royalty income received during the three-month period ended September 30, 2012 totaled $18.3 million compared to $32.8 million received during the three-month period ended September 30, 2011. Royalty income is a function of production volumes sold attributable to the Royalty Interests and associated prices received. The decrease in royalty income was

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primarily attributable to the Trust’s receipt during the 2011 period of net revenue for production covering a five-month period compared to its receipt during the 2012 period of net revenue for production covering a three-month period and, to a lesser extent, a decrease in prices received for natural gas production. The net revenue distribution from SandRidge received by the Trust during the three-month period ended September 30, 2011 was its first and included royalty income attributable to production for the five-month period from January 1, 2011 to May 31, 2011 of 264 MBbls of oil and 1,830 MMcf of natural gas. The net revenue distribution from SandRidge received by the Trust during the three-month period ended September 2012 included royalty income attributable to production for the three-month period from March 1, 2012 to May 31, 2012 of 157 MBbls of oil and 1,322 MMcf of natural gas. Average prices received for oil and natural gas production, excluding the impact of derivative settlements and post-production expenses, during the three-month period ended September 30, 2012 were $96.17 per Bbl of oil and $2.44 per Mcf of natural gas compared to $92.01 per Bbl of oil and $4.66 per Mcf of natural gas during the three-month period ended September 30, 2011.

Derivative Settlements. The Trust’s derivatives agreement with SandRidge reduces the Trust’s exposure to commodity price volatility attributable to a portion of production from the Royalty Interests through December 31, 2015 through the use of oil fixed price swaps and natural gas collars. Net cash settlements under the derivatives agreement for the three-month period ended September 30, 2012 for production from March 1, 2012 to May 31, 2012 were approximately $3.3 million, which effectively increased the average price received for oil by $2.00 per Bbl to $98.17 per Bbl and increased the average price received for natural gas by $2.23 per Mcf to $4.67 per Mcf ($4.11 per Mcf including the impact of post-production expenses). Net cash settlements received during the 2012 period were due to lower average commodity prices at the time of settlement compared to the contract price of the oil fixed price swaps and natural gas collars. Net cash settlements under the derivatives agreement for the three-month period ended September 30, 2011 for production from April 1, 2011 to May 31, 2011 were approximately $56,000, which effectively decreased the average price received for oil by $0.61 per Bbl to $91.40 per Bbl and increased the average price received for natural gas by $0.12 per Mcf to $4.78 per Mcf ($4.24 per Mcf including the impact of post-production expenses). Net cash settlements received during the 2011 period were comprised of gains on natural gas collars due to lower average natural gas prices at the time of settlement compared to contract prices, partially offset by losses on oil fixed price swaps due to higher average oil prices at the time of settlement compared to contract prices.

Post-Production Expenses. The Trust bears post-production expenses attributable to production from the Royalty Interests. Post-production expenses generally consist of costs incurred to gather, store, compress, transport, process, treat, dehydrate and market the oil and natural gas produced. Post-production expenses for the three-month period ended September 30, 2012 totaled approximately $0.7 million compared to approximately $1.0 million for the three-month period ended September 30, 2011. Expense for the period ended September 30, 2011 is attributable to five months of production compared to three months of production for the period ended September 30, 2012.

Production Taxes. Production taxes are calculated as a percentage of oil and natural gas revenues, excluding the effects of derivative settlements and net of any applicable tax credits. Production taxes for the three-month period ended September 30, 2012 totaled approximately $0.2 million, or $0.49 per Boe, and were approximately 1.0% of royalty income. Production taxes for the three-month period ended September 30, 2011 totaled approximately $0.3 million, or $0.59 per Boe, and were approximately 1.0% of royalty income.

Trust Administrative Expenses. Trust administrative expenses generally consist of fees paid to the Trustee and the Delaware Trustee, administrative services fees paid to SandRidge, tax return and related form preparation fees, legal and accounting fees, and other expenses incurred as a result of being a publicly traded entity. Trust administrative expenses for the three-month period ended September 30, 2012 totaled approximately $0.3 million compared to approximately $0.5 million for the three-month period ended September 30, 2011. Included in administrative expenses for the three-month period ended September 30, 2011 are the Trustee’s and the Delaware Trustee’s legal expenses incurred in forming the Trust as well as the Trustee’s one-time acceptance fee.

Distributable Income. Distributable income for the three-month period ended September 30, 2012 was $20.4 million, which included a net addition to the cash reserve for payment of future Trust expenses of approximately $20,000 (approximately $285,000 withheld from the August 2012 cash distribution to unitholders partially offset by approximately $265,000 used to pay Trust expenses during the period). Distributable income for the three-month period ended September 30, 2011 was $29.9 million, which included a net reduction to establish a cash reserve for payment of future Trust expenses of approximately $1.1 million ($1.6 million withheld from the August 2011 cash distribution to unitholders partially offset by approximately $0.5 million used to pay Trust expenses during the period).

Nine Months Ended September 30, 2012 Compared to the Nine Months Ended September 30, 2011

Royalty Income. Royalty income received during the nine-month period ended September 30, 2012 totaled $61.4 million compared to $32.8 million received during the nine-month period ended September 30, 2011. The increase in royalty income is primarily attributable to the Trust’s receipt during the 2011 period of net revenue for production covering a five-month period compared to its receipt during the 2012 period of net revenue for production covering a nine-month period, partially offset by a

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decrease in prices received for natural gas production. The Trust received one net revenue distribution from SandRidge during the nine-month period ended September 30, 2011 that included royalty income attributable to production for the five-month period from January 1, 2011 to May 31, 2011 of 264 MBbls of oil and 1,830 MMcf of natural gas. During the nine-month period ended September 30, 2012, the Trust received net revenue distributions from SandRidge including royalty income attributable to production for the nine-month period from September 1, 2011 to May 31, 2012 of 511 MBbls of oil and 4,351 MMcf of natural gas. Average prices received for oil and natural gas production, excluding the impact of derivative settlements and post-production expenses, during the nine-month period ended September 30, 2012 were $91.94 per Bbl of oil and $3.32 per Mcf of natural gas compared to $92.01 per Bbl of oil and $4.66 per Mcf of natural gas during the nine-month period ended September 30, 2011.

Derivative Settlements. Net cash settlements under the derivatives agreement for the nine-month period ended September 30, 2012 for production from September 1, 2011 to May 31, 2012 were approximately $8.1 million, which effectively increased the average price received for oil by $4.67 per Bbl to $96.61 per Bbl and increased the average price received for natural gas by $1.31 per Mcf to $4.63 per Mcf ($4.08 per Mcf including the impact of post-production expenses). Net cash settlements received during the 2012 period were due to lower average commodity prices at the time of settlement compared to the contract price of the oil fixed price swaps and natural gas collars. Net cash settlements under the derivatives agreement for the nine-month period ended September 30, 2011 were approximately $56,000, which effectively decreased the average price received for oil by $0.61 per Bbl to $91.40 per Bbl and increased the average price received for natural gas by $0.12 per Mcf to $4.78 per Mcf ($4.24 per Mcf including the impact of post-production expenses). Net cash settlements received during the 2011 period were comprised of gains on natural gas collars due to lower average natural gas prices at the time of settlement compared to contract prices, partially offset by losses on fixed oil price swaps due to higher average oil prices at the time of settlement compared to contract prices.

Post-Production Expenses. Post-production expenses for the nine-month period ended September 30, 2012 totaled approximately $2.4 million compared to $1.0 million for the nine-month period ended September 30, 2011. Expense for the period ended September 30, 2011 is attributable to five months of production compared to nine months of production for the period ended September 30, 2012.

Production Taxes. Production taxes for the nine-month period ended September 30, 2012 totaled approximately $0.6 million, or $0.51 per Boe, and were approximately 1.0% of royalty income. Production taxes for the nine-month period ended September 30, 2011 totaled approximately $0.3 million, or $0.59 per Boe, and were approximately 1.0% of royalty income.

Trust Administrative Expenses. Trust administrative expenses for the nine-month period ended September 30, 2012 totaled approximately $1.2 million compared to approximately $0.5 million for the nine-month period ended September 30, 2011. Because the Royalty Interests were conveyed to the Trust in April 2011, expense for the period ended September 30, 2011 is attributable to five months of activity compared to nine months of activity for the period ended September 30, 2012.

Incentive Distribution to SandRidge. Cash available for distribution during the nine-month period ended September 30, 2012 prior to incentive calculations exceeded Incentive Thresholds for the applicable distribution periods by approximately $1.8 million ($1.7 million for the February 2012 distribution and $0.1 million for the May 2012 distribution). As the holder of the Trust’s subordinated units, SandRidge received 50% of the amount by which the cash available for distribution exceeded the Incentive Threshold for each distribution, or approximately $0.9 million total. There were no incentive distributions for the nine-month period ended September 30, 2011.

Distributable Income. Distributable income for the nine-month period ended September 30, 2012 was $64.6 million, which included a net reduction to the cash reserve for payment of future Trust expenses of approximately $0.2 million (approximately $1.2 million used to pay Trust expenses during the period partially offset by approximately $1.0 million withheld from the February 2012, May 2012 and August 2012 cash distributions to unitholders). Distributable income for the nine-month period ended September 30, 2011 was $29.9 million, which included a net reduction to establish a cash reserve for payment of future Trust expenses of approximately $1.1 million ($1.6 million withheld from the August 2011 cash distribution to unitholders partially offset by approximately $0.5 million used to pay Trust expenses during the period).

Liquidity and Capital Resources

The Trust’s principal sources of liquidity and capital are cash flow generated from the Royalty Interests, derivative contracts under the derivatives agreement and borrowings to fund administrative expenses, including any amounts borrowed under SandRidge’s loan commitment described in Note 4 to the unaudited financial statements contained in Part I, Item I of this Quarterly Report. The Trust’s primary uses of cash are distributions to Trust unitholders, including, if applicable, incentive distributions to SandRidge, payment of amounts owed under the derivatives agreement, payment of Trust administrative expenses, including any reserves established by the Trustee for future liabilities, and payment of expense reimbursements to SandRidge for out-of-pocket expenses incurred on behalf of the Trust. Under the conveyances granting the Royalty Interests, the Trust does not have any capital requirements related to drilling wells or any other operating and capital costs related to the wells.

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Administrative expenses include payments to the Trustee and the Delaware Trustee as well as a quarterly fee to SandRidge pursuant to an administrative services agreement. Each quarter, the Trustee determines the amount of funds available for distribution. Available funds are the excess cash, if any, received by the Trust from the sale of oil and natural gas production attributable to the Royalty Interests for the quarter, over the Trust’s expenses for the quarter, subject in all cases to the subordination and incentive provisions previously described. If at any time the Trust’s cash on hand (including available cash reserves) is not sufficient to pay the Trust’s ordinary course administrative expenses as they become due, the Trust may borrow funds from the Trustee or other lenders, including SandRidge, to pay such expenses. If such funds are borrowed, no further distributions will be made to unitholders (except in respect of any previously determined quarterly distribution amount) until the borrowed funds have been repaid. There was no such loan outstanding at September 30, 2012 or December 31, 2011.

Under the derivatives agreement, SandRidge pays the Trust amounts it receives from its counterparties and the Trust pays SandRidge any amounts that SandRidge is required to pay such counterparties. Significant payments by the Trust to SandRidge to cover such settlements could reduce or eliminate distributions paid to unitholders.

2012 Trust Distributions to Unitholders. During the nine-month period ended September 30, 2012, the Trust’s distributions to unitholders were as follows:

Future Trust Distribution to Unitholders. On November 1, 2012, the Trust declared a cash distribution of $0.683076 per unit covering production for the period from June 1, 2012 to August 31, 2012 for record holders as of November 14, 2012. The distribution will be paid on or about November 29, 2012 and was calculated as follows (in thousands, except for unit and per unit amounts):

ITEM 3. Quantitative and Qualitative Disclosures about Market Risk

This discussion provides information about commodity derivative contracts, the benefits and obligations of which SandRidge has passed to the Trust pursuant to a derivatives agreement effective April 1, 2011. Under the derivatives agreement, SandRidge pays the Trust amounts it receives from counterparties under certain of its derivative contracts with third parties, and the Trust pays SandRidge any amounts that SandRidge is required to pay the counterparties under such derivative contracts. The Trust did not bear any costs related to establishing the contracts underlying the derivatives agreement. The commodity derivative contracts underlying the derivatives agreement are settled in cash and do not require the actual delivery of a commodity at settlement. Fixed price swap and collar contracts are settled based upon New York Mercantile Exchange prices. Collar contracts result in a cash settlement only when

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the settlement price exceeds the fixed ceiling price or falls below the fixed floor price. The contracts underlying the derivatives agreement cover a portion of the anticipated future sales volumes of oil and natural gas production from the Initial Wells as well as a portion of the anticipated future production from the Trust Development Wells through December 31, 2015. The Trust does not have the ability to enter into its own derivative contracts. See Note 5 to the unaudited financial statements contained in Part I, Item I of this Quarterly Report for notional and price information of the Trust’s open oil and natural gas derivative contracts. The Trust received net settlement proceeds of approximately $3.3 million and $8.1 million related to the derivatives agreement during the three and nine-month periods ended September 30, 2012, respectively.

Commodity Price Risk. Because the Trust’s primary asset and source of income is the Royalty Interests, which generally entitles the Trust to receive a portion of the net proceeds from sales of oil and natural gas production from the Underlying Properties, the Trust’s most significant market risk relates to the prices received for oil and natural gas production. The derivative contracts described above are intended to mitigate a portion of the variability of oil and natural gas prices received for the Trust’s share of production from the Underlying Properties.

Credit Risk. A portion of the Trust’s liquidity is concentrated in the derivative contracts described above. The use of derivative contracts, including the arrangement between the Trust and SandRidge, involves the risk that SandRidge or its counterparties will be unable to meet their obligations under the contracts. The Trust’s counterparty under the derivatives agreement is SandRidge, whose counterparties are institutions with an “investment grade” credit rating. SandRidge is not required to pay the Trust to the extent of payment defaults by SandRidge’s counterparties.

ITEM 4. Controls and Procedures

The Trustee conducted an evaluation of the Trust’s disclosure controls and procedures, as defined in Rules 13a-15 and 15d-15 under the Securities Act, designed to ensure that information required to be disclosed by the Trust in the reports that it files or submits under the Exchange Act is recorded, processed, summarized and reported within the time periods specified in the SEC’s rules and forms. Based on this evaluation, the Trustee has concluded that the disclosure controls and procedures of the Trust are effective as of the end of the period covered by this report. In its evaluation of disclosure controls and procedures, the Trustee has relied, to the extent considered reasonable, on information provided by SandRidge.

Due to the nature of the Trust as a passive entity and in light of the contractual arrangements pursuant to which the Trust was created, including the provisions of (i) the trust agreement, (ii) the administrative services agreement, (iii) the development agreement and (iv) the conveyances granting the Royalty Interests, the Trustee’s disclosure controls and procedures related to the Trust necessarily rely on (A) information provided by SandRidge, including information relating to results of operations, the status of drilling of the Trust Development Wells, the costs and revenues attributable to the Trust’s interests under the conveyance and other operating and historical data, plans for future operating and capital expenditures, reserve information, information relating to projected production, and other information relating to the status and results of operations of the Underlying Properties and the Royalty Interests, and (B) conclusions and reports regarding reserves by the Trust’s independent reserve engineers.

There were no changes in the Trust’s internal control over financial reporting during the quarter ended September 30, 2012, that have materially affected, or are reasonably likely to materially affect, the Trustee’s internal control over financial reporting. The Trustee notes for purposes of clarification that it has no authority over, has not evaluated and makes no statement concerning, the internal control over financial reporting of SandRidge.

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PART II. Other Information

ITEM 1A. Risk Factors

Risk factors relating to the Trust are contained in Item 1A of the Trust’s Annual Report on Form 10-K for the fiscal year ended December 31, 2011. No material change to such risk factors has occurred during the nine-month period ended September 30, 2012.

ITEM 6. Exhibits

See the Exhibit Index accompanying this Quarterly Report.

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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.

Date: November 13, 2012

The registrant, SandRidge Mississippian Trust I, has no principal executive officer, principal financial officer, board of directors or persons performing similar functions. Accordingly, no additional signatures are available, and none have been provided. In signing the report above, the Trustee does not imply that it has performed any such function or that any such function exists pursuant to the terms of the trust agreement under which it serves.

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EXHIBIT INDEX

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