Oklahoma City, Oklahoma 73104

(405)
429-5500

(Address, including zip code, and telephone number, including area code, of registrant’s principal executive offices)

Salah Gamoudi

Chief Financial Officer

1 E. Sheridan Ave, Suite 500

Oklahoma City, Oklahoma 73104

(405) 429-5500

(Name, address, including zip code, and telephone number, including area code, of agent for service)

Copy to:

Michael J. Blankenship

Winston & Strawn LLP

800 Capitol St., Suite 2400

Houston, TX 77002

(713)-651-2600

Table of Contents

        SandRidge and the trust entered into several agreements in connection with the conveyance of the Royalty Interests to the trust, including: (1) a development agreement, which sets forth SandRidge's drilling obligation to the trust with respect to the Trust Development Wells, (2) a derivatives agreement, pursuant to which SandRidge provides the trust with the effect of certain hedge contracts entered into between SandRidge and third parties, (3) an administrative services agreement, which outlines SandRidge's duty to provide administrative services to the trust and (4) a registration rights agreement. These agreements are described in more detail in the documents incorporated by reference into this prospectus. See "Where You Can Find More Information."

        The trust's business and affairs are managed by the trustee. The trust is passive in nature and none of the trust, the trusteeprospectus or the Delaware trustee has any control over,prospectus supplement or responsibility for, the operation of the Underlying Properties or the costs thereof. The Delaware trustee has only minimal rights and duties as are necessary to satisfy the requirements of having a trustee in Delaware who will accept service of process on the trust under the Delaware Statutory Trust Act. The trust agreement generally limits the trust's business activities to owning the Royalty Interests and any activity reasonably related to such ownership, including activities required or permitted by the terms of the conveyances related to the Royalty Interests and a derivatives agreement between the trust and SandRidge. Although SandRidge operates a substantial number of the properties from which the trust obtains royalties, SandRidge has no ability to manage or influence the management of the trust (except through its limited voting rights as a holder of trust units) and, to the fullest extent permitted by law, owes no fiduciary duties to the trust or the unitholders.

        The trust is responsible for paying all legal, accounting, tax advisory, engineering, printing costs and other administrative and out-of-pocket expenses incurred by or at the direction of the trustee or the Delaware trustee, including tax return and Schedule K-1 preparation and mailing costs, independent auditor fees and registrar and transfer agent fees. The trust is also responsible for administrative expenses incurred as a result of being a publicly traded entity, including costs associated with annual and quarterly reports to unitholders. SandRidge will bear all costs and expenses incidental to the preparation and filing of the registration statement of which thisissuer free writing prospectus, forms a part, excluding certain internal expenses of the trust, which will be borne by the trust, and any underwriting discounts and commissions, which will be borne by the selling unitholder.

        The following chart shows the relationship among the trust, the trustee, SandRidge and the public unitholders before giving effect to any offering by the selling unitholder.

*

Before giving effect to any offering by the selling unitholder pursuant to this prospectus, SandRidge, through SandRidge E&P, owned 528,063 common units and 7,000,000 subordinated

Table of Contents

units, together representing 26.9% of outstanding trust units, while public unitholders (that is, holders of trust units other than SandRidge) owned 20,471,937 common units, representing 73.1% of outstanding trust units. After giving effect to the sale of 528,063 common units by the selling unitholder, SandRidge, through SandRidge E&P, will own no common units and 7,000,000 subordinated units, representing 25.0% of outstanding trust units, while public unitholders will own 21,000,000 common units, representing 75.0% of outstanding trust units. See "Selling Unitholder."

Table of Contents

RISK FACTORS

You should carefully consider the risks described below before making an investment decision. Neither the delivery of this prospectus or any prospectus supplement or any issuer free writing prospectus nor any sale made hereunder shall under any circumstances imply that the information contained or incorporated by reference herein or in any prospectus supplement or issuer free writing prospectus is correct as of any date subsequent to the date hereof or of such prospectus supplement or issuer free writing prospectus, as applicable. You should assume that the information appearing in this prospectus, any prospectus supplement or any document incorporated by reference is accurate only as of the date of the applicable documents, regardless of the time of delivery of this prospectus or any sale of securities. Our business, financial condition, results of operations and prospects may have changed since that date.

Unless the context requires otherwise or unless otherwise noted, all references to “we,” “our,” “us” or like terms refer, after the consummation of the Plan (as defined below), to the Company and, prior to the consummation of the Plan, to our predecessor and its business, assets and operations that were contributed to the Company in connection with the consummation of the Plan.

Table of Contents

•

environmental hazards, such as oil and natural gas leaks, pipeline ruptures and discharges of toxic gases or well fluids;



•

adverse weather conditions, such as extreme cold, fires caused by extreme heat or lack of rain and severe storms or tornadoes;



•

reductions in oil and natural gas prices;



•

oil and natural gas property title problems; and



•

market limitations for oil and natural gas.

        Infree writing prospectus, we intend to use the event that drilling of the Remaining Development Wells is delayed or the Initial Wells or Trust Development Wells have lower than anticipated production due to one of the factors above or for any other reason, cash distributions to unitholders may be reduced. In addition, wells drilled in the Mississippian formation in the AMI typically produce a large volume of water, which requires the drilling of saltwater disposal wells. SandRidge's inability to drill these wells or otherwise dispose of the water produced from the Initial Wells and Trust Development Wells in an efficient manner could delay production and therefore the trust's receipt ofnet proceeds from the Royalty Interests.

         Oil and natural gas prices fluctuate due to a number of factors that are beyond the control of the trust and SandRidge, and lower prices could reduce proceeds to the trust and cash distributions to unitholders.

        The trust's reserves and quarterly cash distributions are highly dependent upon the prices realized from the sale of oil and natural gas. The marketssecurities we are offering for these commodities are very volatile. Oil and natural gas prices can fluctuate widely in response to a variety of factors that are beyond the control of the trust and SandRidge.general corporate purposes. These factorspurposes may include, among others:

•

regional, domestic and foreign supply of, and demand for, oil and natural gas, as well as perceptions of supply of, and demand for, oil and natural gas;



•

the price of foreign imports;



•

U.S. and worldwide political and economic conditions;



•

the level of demand, and perceptions of demand, for oil and natural gas;



•

weather conditions and seasonal trends;



•

anticipated future prices of oil and natural gas, alternative fuels and other commodities;



•

technological advances affecting energy consumption and energy supply;



•

the proximity, capacity, cost and availability of pipeline infrastructure, treating, transportation and refining capacity;



•

natural disasters and other acts of force majeure;



•

domestic and foreign governmental regulations and taxation;



•

energy conservation and environmental measures; and



•

the price and availability of alternative fuels.

        For oil, from January 1, 2008 through June 30, 2012, the highest monthly settled price on the New York Mercantile Exchange ("NYMEX") was $140.00 per Bbl and the lowest was $41.68 per Bbl. For natural gas, from January 1, 2008 through June 30, 2012, the highest monthly NYMEX settled price was $13.11 per MMBtu (one million British Thermal Units) and the lowest was $2.04 per MMBtu. In addition, the market price of oil and natural gas is generally higher in the winter months

Table of Contents

than during other months of the year due to increased demand for oil and natural gas for heating purposes during the winter season.

        Lower oil and natural gas prices will reduce proceeds to which the trust is entitled and may ultimately reduce the amount of oil and natural gas that is economic to produce from the Underlying Properties. As a result, SandRidge or any third-party operator of any of the Underlying Properties could determine during periods of low oil and natural gas prices to shut in or curtail production from wells on the Underlying Properties. In addition, the operator of the Underlying Properties could determine during periods of low oil and natural gas prices to plug and abandon marginal wells that otherwise may have been allowed to continue to produce for a longer period under conditions of higher prices. Specifically, SandRidge or any third-party operator may abandon at its cost any well or property if it reasonably believes that the well or property can no longer produce oil and natural gas in commercially economic quantities. This could result in termination of the portion of the Royalty Interests relating to the abandoned well or property, and SandRidge would have no obligation to drill a replacement well. In addition, lower oil and natural gas prices could make it more likely that leases in the undeveloped acreage will expire at the end of their respective primary terms as a result of the failure to establish production from such leasehold acreage in commercially paying quantities prior to such date. The volatility of oil and natural gas prices also reduces the accuracy of target distributions to trust unitholders. For a discussion of certain risks related to the trust's hedging arrangements, see "—The hedging arrangements for the trust cover only a portion of the oil and natural gas production attributable to the trust, and such contracts limit the trust's ability to benefit from commodity price increases for hedged volumes above the corresponding hedge price."

         Actual reserves and future production may be less than current estimates, which could reduce cash distributions by the trust and the value of the trust units.

        The value of the trust units and the amount of future cash distributions to the trust unitholders will depend upon, among other things, the accuracyadditions to working capital, repayment or refinancing of existing indebtedness or other corporate obligations, financing of capital expenditures and acquisitions and investment in existing and future projects. Any specific allocation of the reserves estimatednet proceeds of an offering of securities to a specific purpose will be attributable to the Royalty Interests. It is not possible to accurately measure underground accumulations of oil and natural gas in an exact way and estimating reserves is inherently uncertain. As discussed below, the process of estimating oil and natural gas reserves requires interpretations of available technical data and many assumptions. Any significant inaccuracies in these interpretations or assumptions could materially affect the estimated quantities and present value of the trust's reserves. This could result in actual production and revenues for the Underlying Properties being materially less than estimated amounts.

        In order to prepare the estimates of reserves attributable to the Underlying Properties and the trust, production rates and the timing of development expenditures must be projected. In so doing, available geological, geophysical, production and engineering data must be analyzed. The extent, quality and reliability of this data can vary.

        In addition, petroleum engineers are required to make subjective estimates of underground accumulations of oil and natural gas based on factors and assumptions that include:

•

historical production from the area compared with production rates from other producing areas;



•

oil and natural gas prices, production levels, Btu content, production expenses, transportation costs, severance and excise taxes and capital expenditures; and



•

the assumed effect of governmental regulation.

        Changes in these assumptions or actual production costs incurred and results of actual development could materially decrease reserve estimates. Estimates of reserves are also continually subject to revisions based on production history, results of additional exploration and development, price changes, and other factors.

Table of Contents

        Reserve estimates for fields that do not have a lengthy production history are less reliable than estimates for fields with lengthy production histories. Less production history may contribute to less accurate estimates of reserves, future production rates and the timing of development expenditures. Of the 37 Initial Wells and 79 Trust Development Wells drilled through June 30, 2012, most have been operational for less than two years and estimated reserves vary substantially from well to well and are not directly correlated to perforated lateral length or completion technique. Although SandRidge and Netherland, Sewell & Associates, Inc. ("Netherland Sewell"), the independent third-party engineering firm that estimated the trust's reserves, analyzed historical production data from vertical wells drilled in the AMI since the 1940s, there can be no assurance that this data can accurately predict future production from horizontal wells. The lack of operational history for horizontal wells in the Mississippian formation may also contribute to the inaccuracy of estimates of reserves. A material and adverse variance of actual production, revenues and expenditures from those underlying reserve estimates would have a material adverse effect on the financial condition, results of operations and cash flows of the trust and would reduce cash distributions to trust unitholders. As with all horizontal drilling programs, there is a risk that some or all of a horizontal well could miss the target reservoir. As a result, the trust may not receive the benefit of the total amount of reserves reflected in the reserve report, notwithstanding the fact that SandRidge has satisfied its drilling obligation.

        The average perforated interval length of the wells assumed for purposes of calculating the proven, undeveloped reserves (exceeding 4,000 feet) is longer than the minimum perforated interval length required for SandRidge to receive credit for one full Trust Development Well under the development agreement (2,500 feet). Further, there is no guarantee that wells drilled with shorter perforated interval lengths will achieve the same reserve recoveries as wells drilled with longer perforated interval lengths. Moreover, as with all horizontal drilling programs, there are risks that some or all of a horizontal well could miss the target reservoir and that the quality of the target reservoir is less than that assumed for purposes of the trust's reserve reports. Under the development agreement, SandRidge receives credit for drilling a Trust Development Well if the well is drilled in the AMI and perforated horizontally for completion in the Mississippian formation, even if such well does not successfully produce hydrocarbons. As a result, unitholders may not receive the benefit of the total amount of proved undeveloped reserves reflected in the trust's reserve reports, even if SandRidge has satisfied its drilling obligation.

         In certain circumstances the trust may have to make cash payments under the derivatives agreement and these payments could be significant.

        If oil or natural gas prices rise, the trust may be obligated to make cash payments to SandRidge which could, in certain circumstances, be significant. Swap contracts underlying the derivatives agreement between SandRidge and the trust provide the trust with the right to receive from SandRidge the excess of the fixed price specified in the hedge contract over a floating market price, multiplied by the volume of production hedged. If the floating market price exceeds the specified fixed price, the trust must pay SandRidge this difference in price multiplied by the volume of production hedged, even if the production attributable to the Royalty Interests is insufficient to cover the volume of production specified in the applicable hedge contracts. Accordingly, if the production attributable to the Royalty Interests is less than the volume hedged and the floating market price exceeds the specified fixed price, the trust will have to make payments against which it will have insufficient offsetting cash receipts from the sale of production attributable to the Royalty Interests. Furthermore, if one or more of the purchasers of the production attributable to the Underlying Properties defaults on a payment obligation, the trust may have insufficient cash receipts to make payments to SandRidge under the derivatives agreement. If these payments become too large, the trust's liquidity and cash available for distribution may be adversely affected.

Table of Contents

         Estimates of the target distributions to unitholders, subordination thresholds and incentive thresholds are based on assumptions made in early 2011 that, when made, were inherently subjective and subject to significant business, economic, financial, legal, regulatory and competitive risks and uncertainties that could cause actual cash distributions to differ materially from those estimated.

        The estimates of target distributions to unitholders, subordination thresholds and incentive thresholds, as set forth in this prospectus and the documents incorporated by reference herein, were based on SandRidge's calculations, and SandRidge did not receive an opinion or report on such calculations from any independent accountants, financial advisers, or engineers. Such calculations were based on assumptions made in early 2011 about drilling, production, oil and natural gas prices, hedging activities, capital expenditures, expenses, tax rates and production tax credits under state law, the location of Trust Development Wells and other matters that were inherently uncertain and were subject to significant business, economic, financial, legal, regulatory and competitive risks and uncertainties that could cause actual results to differ materially from those estimated. For example, these estimates assumed that oil and natural gas production would be sold at prices consistent with settled NYMEX prices for January, February and March 2011 and NYMEX forward pricing as of March 18, 2011 for the remainder of the period ending December 31, 2013, and assumed price increases after December 31, 2013 of 2.5% annually, capped at $120.00 per Bbl of oil in 2025 and $7.00 per MMBtu of natural gas in 2022, respectively. However, actual sales prices may be significantly lower. Additionally, these estimates assumed that the Development Wells would be drilled on SandRidge's anticipated drilling scheduledetermined at the time of the estimates. However,offering and will be described in an accompanying prospectus supplement or free writing prospectus.

Table of Contents

subordinated units will automatically convert into common units on a one-for-one basis, following which they will no longer be subject to the subordination threshold at the enddiscretion of the fourth full calendar quarter following SandRidge's satisfactionour board of its drilling obligation with respect to the Trust Development Wells. Depending on the prices at which volumes attributable to the trust are sold, the common units may receive a distribution that is below the subordination threshold.

        Quarterly cash distributions will be made by the trust based on the proceeds received by the trust pursuant to the Royalty Interests for the preceding calendar quarter. If a quarterly cash distribution is lower than the target distribution amount or subordination threshold for any quarter, the common units will not be entitled to receive any additional distributions nor will the units be entitled to arrearages in any future quarter.

         For Trust Development Wells drilled on properties where SandRidge is not the operator, SandRidge will rely on third-party operators to drill the Trust Development Wells,directors (the “Board”) and for those Trust Development Wells where SandRidge is the operator, SandRidge may rely on third-party servicers to conduct the drilling operations.

        SandRidge owns a majority working interest in substantially all of the locations on which it expects to drill the Trust Development Wells, and it expects to operate such wells during the subordination period. For Trust Development Wells drilled on properties where SandRidge is not the operator, however, SandRidge will rely on third-party operators to drill the Trust Development Wells. In addition, where SandRidge is the operator of a Trust Development Well, it may rely on third-party servicers to perform the necessary drilling operations. The ability of third-party servicers to perform such drilling operations will depend on those servicers' financial condition and economic performance and access to capital, which in turn will depend upon the supply and demand for oil and natural gas, prevailing economic conditions and financial, business and other factors. The failure of a third-party servicer to adequately perform operations could delay drilling or completion or reduce production from the Underlying Properties and the cash available for distribution to trust unitholders. If the Trust Development Wells take longer to be drilled and perforated for completion than currently anticipated, this may delay revenue earned from the production of oil and natural gas by such wells. The revenues distributable to the trust and the amount of cash distributable to the trust unitholders would similarly be delayed.

        Because SandRidge does not have a majority working interest in the non-operated properties comprising the Underlying Properties, SandRidge may not be able to remove the operator in the event of poor or untimely performance. If the Trust Development Wells take longer to be drilled than currently anticipated, this may delay revenue attributable to the production of oil and natural gas by such wells. The revenues distributable to the trust and the amount of cash distributable to the trust unitholders would similarly be delayed.

         Production of oil and natural gas on the Underlying Properties could be materially and adversely affected by severe or unseasonable weather.

        Production of oil and natural gas on the Underlying Properties could be materially and adversely affected by severe weather. Repercussions of severe weather conditions may include:

•

evacuation of personnel and curtailment of operations;



•

weather-related damage to drilling rigs or other facilities, resulting in suspension of operations;



•

inability to deliver materials to worksites; and



•

weather-related damage to pipelines and other transportation facilities.

Table of Contents

        In addition, hydraulic fracturing operations require significant quantities of water. Any diminished access to water for use in hydraulic fracturing, whether due to usage restrictions or drought or other weather conditions, could curtail operations on the Underlying Properties or otherwise result in delays in operations or increased costs.

         Shortages or increases in costs of equipment, services and qualified personnel could delay the drilling of the Remaining Development Wells and result in a reduction in the amount of cash available for distribution.

        The demand for qualified and experienced personnel to conduct field operations, geologists, geophysicists, engineers and other professionals in the oil and natural gas industry can fluctuate significantly, often in correlation with oil and natural gas prices, causing periodic shortages. Historically, there have been shortages of drilling rigs and other equipment as demand for rigs and equipment has increased along with the number of wells being drilled. These factors also cause significant increases in costs for equipment, services and personnel. Higher oil and natural gas prices generally stimulate demand and result in increased prices for drilling rigs, crews and associated supplies, equipment and services. Shortages of field personnel and equipment or price increases could significantly hinder SandRidge's ability to satisfy its drilling obligation and delay completion of the Remaining Development Wells, which would reduce future distributions to trust unitholders.

         Due to the trust's lack of industry and geographic diversification, adverse developments in the trust's existing area of operation could adversely impact its financial condition,our results of operations, and cash flows and reduce its ability to make distributions to the unitholders.

        The Underlying Properties will be operated for oil and natural gas production only and are focused exclusively in the Mississippian formation in northern Oklahoma. This concentration could disproportionately expose the trust's interests to operational and regulatory risk in that area. Due to the lack of diversification in industry type and location of the trust's interests, adverse developments in the oil and natural gas market or the area of the Underlying Properties, including, for example, transportation or treatment capacity constraints, curtailment of production or treatment plant closures for scheduled maintenance, could have a significantly greater impact on the trust's financial condition, results of operations and cash flows than if the Royalty Interests were more diversified.

         The generation of proceeds for distribution by the trust depends in part on access to and the operation of gathering, transportation and processing facilities. Limitations in the availability of those facilities could interfere with sales of oil and natural gas production from the Underlying Properties.

        The amount of oil and natural gas that may be produced and sold from any well to which the Underlying Properties relate is subject to curtailment in certain circumstances, such as by reason of weather conditions, pipeline interruptions due to scheduled and unscheduled maintenance, failure of tendered oil and natural gas to meet quality specifications of gathering lines or downstream transporters, excessive line pressure which prevents delivery, physical damage to the gathering system or transportation system or lack of contracted capacity on such systems. The curtailments may vary from a few days to several months. In many cases, SandRidge is provided limited notice, if any, as to when production will be curtailed and the duration of such curtailments. If SandRidge is forced to reduce production due to such a curtailment, the revenues of the trust and the amount of cash distributions to the trust unitholders would similarly be reduced due to the reduction of proceeds from the sale of production.

        Some of the Trust Development Wells on the Underlying Properties may be drilled in locations that currently are not serviced by natural gas gathering and transportation pipelines or locations in which existing gathering and transportation pipelines do not have sufficient capacity to transport additional production. As a result, the natural gas production from certain Trust Development Wells might not be able to be sold until the necessary gathering systems and/or transportation pipelines are

Table of Contents

constructed or until the necessary transportation capacity on an interstate pipeline is obtained. Any delay in the expansion of such system or the construction or expansion of any other natural gas gathering systems beyond the currently estimated construction schedules, or a delay in the procurement of additional transportation capacity would delay the receipt of any proceeds that may be associated with the natural gas production from the Trust Development Wells.

         Title deficiencies with respect to the Underlying Properties could adversely affect SandRidge's rights to production from the Underlying Properties.

        The existence of title deficiencies with respect to the Underlying Properties could reduce the value or render properties worthless, thus adversely affecting the distributions to unitholders. SandRidge does not obtain title insurance covering oil, gas and mineral leaseholds. Additionally, undeveloped leasehold acreage has greater risk of title defects than developed acreage.

        Drilling title opinions on all of the Underlying Properties have not yet been obtained. Prior to drilling of a Trust Development Well, SandRidge expects to obtain a drilling title opinion to identify defects in title to the leasehold. Frequently, as a result of title examinations, certain curative work may be required to correct identified title defects, and such curative work entails time and expense. The inability or failure to cure title defects could render some locations undrillable or cause the trust to lose its rights to some or all production from some of the Underlying Properties, which could result in a reduction in proceeds available for distribution to unitholders and the value of the trust units if a comparable additional location to drill a Remaining Development Well cannot be identified.

         The trust is passive in nature and has no voting rights in SandRidge, managerial, contractual or other ability to influence SandRidge, or control over the field operations of, sale of oil and natural gas from, or development of, the Underlying Properties.

        Trust unitholders have no voting rights with respect to SandRidge and, therefore, have no managerial, contractual or other ability to influence SandRidge's activities or operations of the Underlying Properties. In addition, some of the Trust Development Wells may be operated by third parties unrelated to SandRidge. Such third-party operators may not have the operational expertise of SandRidge within the AMI. Oil and natural gas properties are typically managed pursuant to an operating agreement among the working interest owners in the properties. The typical operating agreement contains procedures whereby the owners of the aggregate working interest in the property designate one of the interest owners to be the operator of the property. Under these arrangements, the operator is typically responsible for making all decisions relating to drilling activities, sale of production, compliance with regulatorycapital requirements and other matters that affectfactors deemed relevant by our Board. Additionally, covenants contained in certain of our debt instruments restrict the property. payment of cash dividends on our common stock.

Table of Contents

        Future maintenance may affect the quantity of proved reserves that can be economically produced from the Underlying Properties to which the wells relate. The timing and size of these projects will depend on, among other factors, the market prices of oil and natural gas. With the exception of SandRidge's commitment to drill the Trust Development Wells, SandRidge has no contractual obligation to make capital expenditures on the Underlying Properties in the future. Furthermore, for properties on which SandRidge is not designated as the operator, SandRidge has no control over the timing or amount of those capital expenditures. SandRidge also has the right to non-consent and not participate in the capital expenditures on properties for which it is not the operator, in which case SandRidge and the trust will not receive the production resulting from such capital expenditures. If SandRidge or other operators of the wells to which the Underlying Properties relate do not implement maintenance projects when warranted, the future rate of production decline of proved reserves may be higher than the rate currently expected by SandRidge or estimated in the trust's reserve report.

        The trust agreement provides that the trust's business activities are generally limited to owning the Royalty Interests and any activity reasonably related to such ownership, including activities required or permitted by the terms of the conveyances related to the Royalty Interests. As a result, the trust is not permitted to acquire other oil and gas properties or royalty interests to replace the depleting assets and production attributable to the trust.

         An increase in the differential between the price realized by SandRidge for oil and natural gas produced from the Underlying Properties and the NYMEX or other benchmark price of oil or natural gas could reduce the proceeds to the trust and therefore the cash distributions by the trust and the value of trust units.

        The prices received for oil and natural gas production usually fall below benchmark prices such as NYMEX. The difference between the price received and the benchmark price is called a differential. The amount of the differential will depend on a variety of factors, including discounts based on the quality and location of hydrocarbons produced, Btu content and post-production costs. These factors can cause differentials to be volatile from period to period. Sellers of production have little or no control over the factors that determine the amount of the differential, and cannot accurately predict differentials for oil or natural gas. Increases in the differential between the realized price of oil or natural gas and the benchmark price for oil or natural gas could reduce the proceeds to the trust and therefore the cash distributions made by the trust and the value of the trust units. The target distributions were prepared (a) for natural gas using an assumed negative differential of 19% from NYMEX futures prices for natural gas, and (b) for oil using an assumed negative differential of $5.00 per barrel from NYMEX futures prices for oil.

         The amount of cash available for distribution by the trust is reduced by post-production costs and applicable taxes associated with the Royalty Interests, trust expenses and incentive distributions payable to SandRidge.

        The Royalty Interests and the trust bear certain costs and expenses that reduce the amount of cash received by or available for distribution by the trust to the holders of the trust units. These costs and expenses include the following:

•

the trust's share of the costs incurred by SandRidge to gather, store, compress, transport, process, treat, dehydrate and market the oil and natural gas (excluding costs of marketing services provided by SandRidge);



•

the trust's share of applicable taxes, including taxes on the production of oil and natural gas;



•

trust administrative expenses, including fees paid to the trustee and the Delaware trustee, the annual administrative services fee payable to SandRidge, tax return and Schedule K-1 preparation and mailing costs, independent auditor fees and registrar and transfer agent fees, and costs associated with annual and quarterly reports to unitholders; and

Table of Contents

•

any amounts owed to counterparties under the hedging contracts underlying the derivatives agreement.

        In addition, the amount of funds available for distribution to unitholders is reduced by the amount of any cash reserves maintained by the trustee in respect of anticipated future trust administrative expenses.

        Further, during the subordination period, SandRidge is entitled to receive a quarterly incentive distribution from the trust equal to 50% of the amount by which cash available to be paid to all unitholders exceeds the incentive threshold for the applicable quarter.

        The amount of post-production costs, taxes and expenses borne by the trust and incentive distributions payable to SandRidge may vary materially from quarter-to-quarter. The extent by which the costs and expenses of the trust are higher or lower in any quarter will directly decrease or increase the amount received by the trust and available for distribution to the unitholders. Historical post-production costs and taxes, however, may not be indicative of future post-production costs and taxes.

         The hedging arrangements for the trust cover only a portion of the oil and natural gas production attributable to the trust, and such contracts limit the trust's ability to benefit from commodity price increases for hedged volumes above the corresponding hedge price.

        Pursuant to the derivatives agreement, SandRidge has provided the trust with the effect of certain oil and natural gas hedging contracts that it has entered into with third parties. The derivatives agreement covers only a portion of the estimated oil and natural gas production attributable to the Royalty Interests, and will terminate after December 31, 2015. The trust's receipt of any payments due to it based on the derivatives agreement depends upon the financial position of SandRidge and SandRidge's hedge contract counterparties. A default by SandRidge or any of the hedge contract counterparties could reduce the amount of cash available for distribution to the trust unitholders. See "—SandRidge's ability to satisfy its obligations to the trust depends on its financial position, and in the event of a default by SandRidgequalified in its obligationentirety by reference to drill the Trust Development Wells, or in the eventour Certificate of SandRidge's bankruptcy, it may be expensiveIncorporation and time-consuming for the trust to exercise its remedies."

        Pursuant to the derivatives agreement, 45% of the expected productionour Bylaws, and approximately 56% of the expected revenues upon which the target distributions were based from July 1, 2012 through December 31, 2015 have been hedged. The remaining estimated production of oil and natural gas during that time and all production after such time will not be hedged to protect against the price risks inherent in holding interests in oil and natural gas, a commodity that is frequently characterized by significant price volatility. Furthermore, while the use of hedging arrangements limits the downside risk of price declines, they may also limit the trust's ability to benefit from increases in oil and natural gas prices above the hedge price on the portion of the production attributable to the Royalty Interests that is hedged. The trust does not have any ability to terminate the hedging contracts.

        The trust's counterparty under the derivatives agreement is SandRidge, whose counterparties are Deutsche Bank AG London Branch, Credit Suisse Energy, LLC, and Royal Bank of Canada. In the event that any of the counterparties to the oil and natural gas hedging contracts defaults on its obligations to make payments under such contracts, the cash distributions to the trust unitholders would likely be materially reduced as the hedge payments are intended to provide additional cash to the trust during periods of lower oil and natural gas prices. SandRidge will not be required to make payments to the trust under the derivatives agreement to the extent of payment defaults by SandRidge's hedge contract counterparties. The trust has no ability to enter into its own hedges.

Table of Contents

         The trust is managed by a trustee who cannot be replaced except at a special meeting of trust unitholders.

        The business and affairs of the trust are managed by the trustee. A unitholder's voting rights are more limited than those of stockholders of most public corporations. For example, there is no requirement for annual meetings of trust unitholders or for an annual or other periodic re-election of the trustee. The trust agreement provides that the trustee may only be removed and replaced by the holders of a majority of the outstanding trust units, excluding trust units held by SandRidge, voting in person or by proxy at a special meeting of trust unitholders at which a quorum is present called by either the trustee or the holders of not less than 10% of the outstanding trust units. As a result, it may be difficult for public unitholders to remove or replace the trustee without the cooperation of holders of a substantial percentage of the outstanding trust units.

         Trust unitholders have limited ability to enforceapplicable provisions of the Royalty Interests, and SandRidge's liability to the trust is limited.

        The trust agreement permits the trustee and the trust to sue SandRidge or any other future owner of the Underlying Properties to enforce the terms of the conveyances creating the Royalty Interests. If the trustee does not take appropriate action to enforce provisions of these conveyances, a trust unitholder's recourse would be limited to bringing a lawsuit against the trustee to compel the trustee to take specified actions. The trust agreement expressly limits a trust unitholder's ability to directly sue SandRidge or any other party other than the trustee. As a result, trust unitholders will not be able to sue SandRidge or any future owner of the Underlying Properties to enforce the trust's rights under the conveyances. Furthermore, the Royalty Interest conveyances provide that, except as set forth in the conveyances, SandRidge will not be liable to the trust for the manner in which it performs its duties in operating the Underlying Properties as long as it acts in good faith and, to the fullest extent permitted by law, will owe no fiduciary duties to the trust or the unitholders.

         Courts outside of Delaware may not recognize the limited liability of the trust unitholders provided under Delaware law.

        Under the Delaware Statutory Trust Act, trust unitholders are entitled to the same limitation of personal liability extended to stockholders of private corporations for profit under the General Corporation Law (the “DGCL”). We urge you to read our Amended and Restated Certificate of Incorporation (the “Certificate of Incorporation”) and our Amended and Restated Bylaws (the “Bylaws”) in their entirety for a complete description of the Staterights and preferences of Delaware. However, courts in jurisdictions outside of Delaware may not give effect to such limitation.

         Sale of trust units by SandRidge could have an adverse impact on the trading price of the common units.

        As of October 5, 2012, SandRidge, through SandRidge E&P, owned an aggregate of 528,063 common units and 7,000,000 subordinated units. All of the subordinated units will automatically convert into common units at the end of the subordination period. SandRidge may sell trust units in the public or private markets, and any such sales could have an adverse impact on the price of the common units or on any trading market that may develop. During 2012, SandRidge sold an aggregate of 3,221,937 common units in three separate transactions under Rule 144 under the Securities Act of 1933 ("Securities Act"). The trust has granted registration rights to SandRidge, which, if exercised, would facilitate sales of trust units by SandRidge to the public. The registration statementour securities, copies of which this prospectus forms a part washave been filed by the trust in accordance with the registration rights granted to SandRidge.

Table of Contents

         SandRidge could have interests that conflict with the interests of the trust and trust unitholders.

        As a working interest owner in the Underlying Properties, SandRidge could have interests that conflict with the interests of the trust and the trust unitholders. For example:

•

Notwithstanding its drilling obligation to the trust, SandRidge's interests may conflict with those of the trust and the trust unitholders in situations involving the development, maintenance, operation or abandonment of the Underlying Properties. Additionally, SandRidge may, consistent with its obligation to act as a reasonably prudent operator, abandon a well that is uneconomic or not generating revenues from production in excess of its operating costs, even though such well is still generating revenue for the trust unitholders. Subsequent to fulfilling its drilling obligation, SandRidge may make decisions with respect to expenditures and decisions to allocate resources on projects in other areas that adversely affect the Underlying Properties, including reducing expenditures on these properties, which could cause oil and natural gas production to decline at a faster rate and thereby result in lower cash distributions by the trust in the future.



•

Following the satisfaction of its drilling obligation to the trust, SandRidge may, without the consent or approval of the trust unitholders, sell all or any part of its retained interest in the Underlying Properties, if the Underlying Properties are sold subject to and burdened by the Royalty Interests. Such sale may not be in the best interests of the trust and trust unitholders. For example, any purchaser may lack SandRidge's experience in the Mississippian formation or its creditworthiness.



•

Following the satisfaction of its drilling obligation to the trust, SandRidge may, without the consent or approval of the trust unitholders, require the trust to release Royalty Interests with an aggregate value of up to $5.0 million during any 12-month period in connection with a sale by SandRidge of a portion of its retained interest in the Underlying Properties. The fair value received by the trust for such Royalty Interests may not fully compensate the trust for the value of future production attributable to the Royalty Interests disposed of.



•

SandRidge is permitted under the conveyance agreements creating the Royalty Interests to enter into new processing and transportation contracts without obtaining bids from or otherwise negotiating with any independent third parties, and SandRidge will deduct from the trust's proceeds any charges under such contracts attributable to production from the trust properties.



•

SandRidge can sell its trust units regardless of the effects such sale may have on common unit prices or on the trust itself. Additionally, SandRidge can vote its trust units in its sole discretion.

        In addition, SandRidge has agreed that, 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 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 arms' length transaction between SandRidge and an unaffiliated third party. If SandRidge provides such funds to the trust, it would become a creditor of the trust and its interests as a creditor could conflict with the interests of unitholders.

         SandRidge may sell all or a portion of the Underlying Properties, subject to and burdened by the Royalty Interests, after satisfying its drilling obligation to the trust; any such purchaser could have a weaker financial position and/or be less experienced in oil and natural gas development and production than SandRidge.

        Unitholders will not be entitled to vote on any sale of the Underlying Properties if the Underlying Properties are sold subject to and burdened by the Royalty Interests and the trust will not receive any proceeds from any such sale. The purchaser would be responsible for all of SandRidge's obligations relating to the Royalty Interests on the portion of the Underlying Properties sold, and SandRidge

Table of Contents

would have no continuing obligation to the trust for those properties. Additionally, SandRidge may enter into farmout or joint venture arrangements with respect to the wells burdened by the trust's Royalty Interest. Any purchaser, farmout counterparty or joint venture partner could have a weaker financial position and/or be less experienced in oil and natural gas development and production than SandRidge.

         SandRidge's ability to satisfy its obligations to the trust depends on its financial position, and in the event of a default by SandRidge in its obligation to drill the Trust Development Wells, or in the event of SandRidge's bankruptcy, it may be expensive and time-consuming for the trust to exercise its remedies.

        Pursuant to the terms of the development agreement between SandRidge and the trust, SandRidge is obligated to drill, or cause to be drilled, the Trust Development Wells at its own expense. SandRidge owns a majority working interest in substantially all of the locations on which it expects to drill the Remaining Development Wells, and it expects to operate such wells until completion of its drilling obligation. As of the date of this prospectus, SandRidge is also the operator of 89% of the Initial Wells together with the wells drilled as Trust Development Wells through June 30, 2012. The conveyances provide that SandRidge is obligated to market, or cause to be marketed, the oil and natural gas production related to the Underlying Properties. Additionally, SandRidge is the counterparty to the trust's derivatives agreement and has certain obligations to the trust under the agreement. In the event that SandRidge defaults on its obligation to make payments under the derivatives agreement, the cash distributions to the trust unitholders may be materially reduced as these payments are intended to provide additional cash to the trust during periods of lower oil and natural gas prices. Due to the trust's reliance on SandRidge to fulfill these numerous obligations, the value of the Royalty Interests and its ultimate cash available for distribution is highly dependent on SandRidge's performance.

        SandRidge has other drilling obligations, including drilling obligations to two other royalty trusts, which will require it to make capital expenditures over the next several years at the same time it plans to drill the Remaining Development Wells. SandRidge's ability to satisfy its drilling obligation to the trust will depend on, among other things, the availability of sufficient funds and drilling rigs. More generally, SandRidge's ability to satisfy its drilling obligation to the trust and to perform these obligations depends on its future financial condition and economic performance and access to capital, which in turn depends upon the supply and demand for oil and natural gas, prevailing economic conditions and financial, business and other factors, many of which are beyond SandRidge's control.

        In the event that SandRidge defaults on its obligation to drill the Remaining Development Wells, the trust would be able to foreclose on the lien granted to the trust by SandRidge E&P in order to secure the estimated amount of the drilling costs for the trust's interests in the undeveloped Underlying Properties (the "Drilling Support Lien") to the extent of SandRidge's remaining interests in the undeveloped portions of the AMI. However, the maximum amount the trust can recover in such a foreclosure or other action was, as of June 30, 2012, approximately $59.9 million, which amount will be reduced proportionately as each Remaining Development Well is drilled and perforated for completion with a perforated length of 2,500 feet. The value of SandRidge's interests in the undeveloped portions of the AMI secured by the Drilling Support Lien may not be equal to the amount recoverable at any given time, and such interests may be worth considerably less. The process of foreclosing on such collateral may be expensive and time-consuming and delay the drilling and completion of the Remaining Development Wells; such delays and expenses would reduce trust distributions by reducing the amount of proceeds available for distribution. Any amounts actually recovered in a foreclosure action would be applied to completion of SandRidge's drilling obligation, would not result in any distribution to the trust unitholders and may be insufficient to drill the number of wells needed for the trust to realize the full value of the Development Royalty Interest. Furthermore, the trust would have to seek a new party to perform the drilling and operations of the wells. The trust may not be able to

Table of Contents

find a replacement driller or operator, and it may not be able to enter into a new agreement with such replacement party on favorable terms within a reasonable period of time.

        SandRidge will not be required to maintain a segregated account for proceeds payable to the trust. The proceeds of the Royalty Interests may be commingled, for a period of time, with proceeds of SandRidge's retained interest in the Underlying Properties for the period of time between SandRidge's sale of hydrocarbons attributable to the Royalty Interests and the quarterly payment to the trust of its share of proceeds. It is possible that the trust may not have adequate facts to trace its entitlement to funds in the commingled pool of funds and that other persons may, in asserting claims against SandRidge's retained interest, be able to assert claims to the proceeds that should be delivered to the trust. If there is an event of default under SandRidge's credit facility, SandRidge must keep its accounts with banks that enter into control agreements with the administrative agent under the credit facility, which would permit the administrative agent to direct payment of funds in such accounts during the pendency of an event of default. In addition, during any bankruptcy of SandRidge, it is possible that payments of the royalties may be delayed or deferred. During the pendency of any SandRidge bankruptcy proceedings, the trust's ability to foreclose on the Drilling Support Lien, and the ability to collect cash payments being held in SandRidge's accounts that are attributable to production from the trust properties, may be stayed by the bankruptcy court. Delay in realizing on the collateral for the Drilling Support Lien is possible, and it cannot be guaranteed that a bankruptcy court would permit such foreclosure. It is possible that the bankruptcy would also delay the execution of a new agreement with another driller or operator. If the trust enters into a new agreement with a drilling or operating partner, the new partner might not achieve the same levels of production or sell oil and natural gas at the same prices as SandRidge was able to achieve.

         Oil and natural gas wells are subject to operational hazards that can cause substantial losses. SandRidge maintains insurance; however, SandRidge may not be adequately insured for all such hazards.

        There are a variety of operating risks inherent in oil and natural gas production and associated activities, such as fires, leaks, explosions, mechanical problems, major equipment failures, blowouts, uncontrollable flow of oil, natural gas, water or drilling fluids, casing collapses, abnormally pressurized formations and natural disasters. The occurrence of any of these or similar accidents that temporarily or permanently halt the production and sale of oil and natural gas at any of the Underlying Properties will reduce trust distributions by reducing the amount of proceeds available for distribution.

        Additionally, if any of such risks or similar accidents occur, SandRidge could incur substantial losses as a result of injury or loss of life, severe damage or destruction of property, natural resources and equipment, regulatory investigation and penalties and environmental damage and clean-up responsibility. If SandRidge experiences any of these problems, its ability to conduct operations and perform its obligations to the trust could be adversely affected. While SandRidge maintains insurance coverage it deems appropriate for these risks with respect to the Underlying Properties, SandRidge's operations may result in liabilities exceeding such insurance coverage or liabilities not covered by insurance. If a well is damaged, SandRidge would have no obligation to drill a replacement well or make the trust whole for the loss.

         The operation of the Underlying Properties is subject to complex federal, state, local and other laws and regulations that could adversely affect the cost, manner and feasibility of conducting operations on the properties, which in turn could negatively impact trust distributions, estimated and actual future net revenues to the trust and estimates of reserves attributable to the trust's interests.

        Oil and natural gas exploration, production, transportation and treatment operations are subject to complex and stringent laws and regulations. In order to conduct operations in compliance with these laws and regulations, numerous permits, approvals and certificates are required from various federal, state and local governmental authorities. Compliance with these existing laws and regulations may

Table of Contents

require the incurrence of substantial costs by SandRidge or other operators of the Underlying Properties. Additionally, there has been a variety of regulatory initiatives at the federal and state levels to further regulate oil and natural gas operations in certain locations. Any increased regulation or suspension of oil and natural gas operations, or revision or reinterpretation of existing laws and regulations, could result in delays and higher operating costs. Such costs or significant delays could have a material adverse effect on the operation of the Underlying Properties, which in turn could negatively impact trust distributions, estimated and actual future net revenues to the trust and estimates of reserves attributable to the trust's interests.

        Laws and regulations governing oil and natural gas exploration and production may also affect production levels. SandRidge is required to comply with federal and state laws and regulations governing conservation matters, including provisions related to the unitization or pooling of the oil and natural gas properties; the establishment of maximum rates of production from wells; the spacing of wells; and the plugging and abandonment of wells. These and other laws and regulations can limit the amount of oil and natural gas SandRidge can produce from its wells, limit the number of wells it can drill, or limit the locations at which it can conduct drilling operations, which in turn could negatively impact trust distributions, estimated and actual future net revenues to the trust and estimates of reserves attributable to the trust's interests.

        New laws or regulations, or changes to existing laws or regulations may unfavorably impact SandRidge, could result in increased operating costs and have a material adverse effect on SandRidge's financial condition and results of operations. For example, Congress has recently considered, and may continue to consider, legislation that, if adopted in its proposed form, would subject companies involved in oil and natural gas exploration and production activities to, among other items, additional regulation of and restrictions on hydraulic fracturing of wells, and the elimination of most U.S. federal tax incentives and certain deductions available to oil and natural gas exploration and production activities. In addition, the Dodd-Frank Wall Street Reform and Consumer Protection Act and rules promulgated thereunder could reduce trading positions in the energy futures markets and materially reduce hedging opportunities for SandRidge, which could adversely affect its revenues and cash flows during periods of low commodity prices, and which could adversely affect the ability to restructure the hedges when it might be desirable to do so.

        Additionally, federal and state regulatory authorities may expand or alter applicable pipeline safety laws and regulations, compliance with which may require increased capital costs on the part of SandRidge and third-party downstream oil and natural gas transporters. These and other potential regulations could increase SandRidge's operating costs, reduce SandRidge's liquidity, delay SandRidge's operations, increase direct and third-party post production costs associated with the trust's interests or otherwise alter the way SandRidge conducts its business, which could have a material adverse effect on SandRidge's financial condition, results of operations and cash flows and which could reduce cash received by or available for distribution, including any amounts paid by SandRidge for transportation on downstream interstate pipelines.

         The operation of the Underlying Properties is subject to environmental laws and regulations that could adversely affect the cost, manner or feasibility of conducting operations or result in significant costs and liabilities.

        The oil and natural gas exploration and production operations on the Underlying Properties are subject to stringent and comprehensive federal, state, and local laws and regulations governing the discharge of materials into the environment or otherwise relating to environmental protection. These laws and regulations may impose numerous obligations that are applicable to operations of the Underlying Properties, including the acquisition of permits before conducting drilling; water withdrawal or waste disposal activities; the restriction of types, quantities and concentrations of materials that can be released into the environment; the limitation or prohibition of drilling activities on certain lands

Table of Contents

lying within wilderness, wetlands and other protected areas; the imposition of regulations designed to protect employees from exposure to hazardous substances; and the imposition of substantial liabilities for pollution resulting from operations. Numerous governmental authorities, such as the EPA and analogous state agencies have the power to enforce compliance with these laws and regulations and the permits issued under them, often requiring difficult and costly actions. Failure to comply with these laws and regulations may result in litigation; the assessment of administrative, civil and criminal penalties; the imposition of investigatory or remedial obligations; and the issuance of injunctions limiting or preventing some or all operations relating to the Underlying Properties.

        There is inherent risk of incurring significant environmental costs and liabilities in the performance of operations at the Underlying Properties due to the handling of petroleum hydrocarbons and wastes, because of air emissions and wastewater discharges related to its operations, and as a result of historical industry operations and waste disposal practices. Under certain environmental laws and regulations, an operator could be subject to joint and several strict liability for the investigation, removal or remediation of previously released materials or property contamination regardless of whether the operator was responsible for the release or contamination or if the operations were in compliance with all applicable laws at the time the release occurred. Private parties, including the owners of properties upon which wells are drilled and facilities where petroleum hydrocarbons or wastes are taken for reclamation or disposal may also have the right to pursue legal actions to enforce compliance,SEC, as well as to seek damages for contamination even in the absence of non-compliance, with environmental laws and regulations or for personal injury or property damage. In addition, the risk of accidental spills or releases could expose an operator to significant liabilities that could have a material adverse effect on its financial condition or results of operations. Changes in environmental laws and regulations occur frequently, and any changes that result in more stringent or costly construction, drilling, water management, completion, waste handling, storage, transport, disposal or cleanup requirements could require significant expenditures by SandRidge or other operators of the Underlying Properties to attain and maintain compliance and may otherwise have a material adverse effect on the results of operations, competitive position or financial condition of SandRidge or such other operator. SandRidge or such other operator may not be able to recover some or any of these costs from insurance. As a result of the increased cost of compliance, SandRidge or such other operator may decide to discontinue drilling. Additionally, permitting delays may inhibit SandRidge's ability to drill the Remaining Development Wells on schedule.

         Climate change laws and regulations restricting emissions of "greenhouse gases" could result in increased operating costs and reduced demand for the oil and natural gas that SandRidge produces while the physical effects of climate change could disrupt SandRidge's production and cause SandRidge to incur significant costs in preparing for or responding to those effects.

        In December 2009, the EPA published its findings that emissions of carbon dioxide, methane and other greenhouse gases ("GHGs") present a danger to public health and the environment. These findings allow the agency to adopt and implement regulations that restrict emissions of GHGs under existingapplicable provisions of the Clean Air Act. Accordingly, the EPA has adopted rules that require a reduction in emissionsDGCL for additional information. The Certificate of GHGs from motor vehiclesIncorporation and also trigger Clean Air Act construction and operating permit review for GHG emissions from certain stationary sources. The EPA's rules relating to emissions of GHGs from stationary sources of emissionsBylaws are subject to a number of political and legal challenges, but the federal courts have thus far declined to issue any injunctions to prevent EPA from implementing, or requiring state environmental agencies to implement, the rules. In addition, the EPA has adopted rules requiring the reporting of GHG emissions from onshore oil and natural gas production facilities in the United States on an annual basis. Both houses of Congress have from time to time considered legislation to reduce emissions of GHGs and almost one-half of the states, either individually or through multi-state regional initiatives, already have begun implementing legal measures to reduce emissions of GHGs. The adoption and implementation of any regulations imposing reporting

Table of Contents

obligations on, or limiting emissions of GHGs from, SandRidge's equipment and operations could require SandRidge to incur additional costs to reduce emissions of GHGs associated with its operations or could adversely affect demand for the oil and natural gas that it produces. Finally, some scientists have concluded that increasing concentrations of GHG in the Earth's atmosphere may produce climate change that could have significant physical effects, such as increased frequency and severity of storms, droughts, and floods and other climatic events; if any such effects were to occur, they could have an adverse effect on the Underlying Properties.

         Federal and state legislative and regulatory initiatives as well as governmental reviews relating to hydraulic fracturing could result in increased costs and additional operating restrictions or delays as well as adversely affect the level of production from the Underlying Properties.

        Hydraulic fracturing is an important and common practice that is used to stimulate production of hydrocarbons from tight formations, such as shales. The process involves the injection of water, sand and chemicals under pressure into formations to fracture the surrounding rock and stimulate production. The process is typically regulated by state oil and gas commissions. Certain states in which SandRidge operates, including Texas and Oklahoma, and municipalities have adopted, or are considering adopting, regulations that have imposed, or that could impose, more stringent permitting, disclosure, disposal and well construction requirements on exploration and production activities. For example, in December 2011, the Railroad Commission of Texas finalized regulations requiring public disclosure of all the chemicals in fluids used in the hydraulic fracturing process. Local ordinances or other regulations may regulate or prohibit the performance of well drilling in general and hydraulic fracturing in particular. If new laws or regulations that significantly restrict or regulate hydraulic fracturing are adopted, such legal requirements could cause project delays and make it more difficult or costly to perform fracturing to stimulate production from a formation. These delays or additional costs could adversely affect the determination of whether a well is commercially viable. Restrictions on hydraulic fracturing could also reduce the amount of oil and natural gas that ultimately can be produced in commercial quantities from the Underlying Properties.

        In addition, a number of federal entities are analyzing, or have been requested to review, a variety of environmental issues associated with unconventional natural gas production, including hydraulic fracturing. In April 2012, President Obama issued an executive order that established a working group for the purpose of coordinating policy, information sharing, and planning among federal agencies and offices regarding "unconventional natural gas production," including hydraulic fracturing. In April 2012, the EPA issued final Clean Air Act regulations governing performance standards, including standards for the capture of air emissions released during hydraulic fracturing that will take effect in 2015. The EPA also has commenced a study of the potential environmental effects of hydraulic fracturing on drinking water and groundwater, with initial results expected to be available by late 2012 and final results by 2014. In May 2012, the U.S. Department of the Interior issued a proposed rule addressing disclosure of chemicals used, well integrity monitoring, flowback fluid management requirements and other mandates for hydraulic fracturing on federal lands. Additionally, a committee of the United States House of Representatives has conducted an investigation of hydraulic fracturing practices, and certain members of Congress have called upon the U.S. Government Accountability Office to investigate how hydraulic fracturing might adversely affect water resources; the SEC to investigate the natural gas industry and any possible misleading of investors or the public regarding the economic feasibility of pursuing natural gas deposits in shales by means of hydraulic fracturing; and the U.S. Energy Information Administration to provide a better understanding of that agency's estimates regarding natural gas reserves, including reserves from shale formations, as well as uncertainties associated with those estimates. Bills introduced in both the Senate and the House of Representatives in 2011 would, among other things, amend the federal Safe Drinking Water Act to repeal provisions that exempt hydraulic fracturing operations from restrictions that otherwise would apply to underground injection of fluids or propping agents. The studies and initiatives described above,

Table of Contents

depending on their degree of pursuit and any meaningful results obtained, could spur efforts to further regulate hydraulic fracturing under the Safe Drinking Water Act or other regulatory mechanisms.

         The trust is subject to the requirements of the Sarbanes-Oxley Act of 2002, which may impose cost and operating challenges on it.

        The trust is subject to certain of the requirements of the Sarbanes-Oxley Act of 2002 which requires, among other things, maintenance by the trust of, and reports regarding the effectiveness of, a system of internal control over financial reporting. Complying with these requirements may pose operational challenges and may cause the trust to incur unanticipated expenses. Any failure by the trust to comply with these requirements could lead to a loss of public confidence in the trust's internal controls and in the accuracy of the trust's publicly reported results.

Tax Risks Related to the Units

         The trust's tax treatment depends on its status as a partnership for U.S. federal income tax purposes. If the U.S. Internal Revenue Service ("IRS") were to treat the trust as a corporation for U.S. federal income tax purposes, then its cash available for distribution to unitholders would be substantially reduced.

        The anticipated after-tax economic benefit of an investment in the trust units depends largely on the trust being treated as a partnership for U.S. federal income tax purposes. The trust has not requested, and does not plan to request, a ruling from the IRS, on this or any other tax matter affecting it.

        It is possible in certain circumstances for a publicly traded trust otherwise treated as a partnership, such as the trust, to be treated as a corporation for U.S. federal income tax purposes. In addition, a change in current law could cause the trust to be treated as a corporation for U.S. federal income tax purposes or otherwise subject it to federal taxation as an entity.

        If the trust were treated as a corporation for U.S. federal income tax purposes, it would pay federal income tax on its taxable income at the corporate tax rate, which is currently a maximum of 35%, and would likely be required to also pay state income tax on its taxable income at the corporate tax rate of such state. Distributions to unitholders would generally be taxed again as corporate distributions, and no income, gains, losses, deductions or credits would flow through to unitholders without first being subjected to taxation at the entity level. Because additional tax would be imposed upon the trust as a corporation, its cash available for distribution to unitholders would be substantially reduced. Therefore, treatment of the trust as a corporation would result in a material reduction in the anticipated cash flow and after-tax return to the trust unitholders, likely causing a substantial reduction in the value of the trust units.

        The trust agreement provides that if a law is enacted or existing law is modified or interpreted in a manner that subjects the trust to additional amounts of entity-level taxation for state or local income tax purposes, the subordination threshold amounts, incentive threshold amounts and target distribution amounts may be adjusted to reflect the impact of that law on the trust.

         If the trust were subjected to a material amount of additional entity-level taxation by individual states, it would reduce the trust's cash available for distribution to unitholders.

        Changes in current state law may subject the trust to additional entity-level taxation by individual states. Because of widespread state budget deficits and other reasons, several states are evaluating ways to subject partnerships to entity-level taxation through the imposition of state income, franchise and other forms of taxation.

        Additional imposition of such taxes may substantially reduce the cash available for distribution to unitholders and, therefore, negatively impact the value of an investment in trust units. The trust

Table of Contents

agreement provides that if a law is enacted or existing law is modified or interpreted in a manner that subjects the trust to additional amounts of entity-level taxation for state or local income tax purposes, the subordination threshold amounts, incentive threshold amounts and target distribution amounts may be adjusted to reflect the impact of that law on the trust.

         The tax treatment of an investment in trust units could be affected by recent and potential legislative changes, possibly on a retroactive basis.

        The Health Care and Education Reconciliation Act of 2010 includes a provision that, in taxable years beginning after December 31, 2012, subjects an individual having adjusted gross income in excess of $200,000 (or $250,000 for married taxpayers filing joint returns) to an additional "Medicare tax" equal generally to 3.8% of the lesser of such excess or the individual's net investment income, which appears to include interest income and royalty income derived from investments such as the trust units as well as any net gain from the disposition of trust units. In addition, absent new legislation extending the current rates, beginning January 1, 2013, the highest marginal U.S. federal income tax rate applicable to ordinary income and long-term capital gains of individuals will increase to 39.6% and 20%, respectively. Moreover, these rates are subject to change by new legislation at any time.

        Current law may change so as to cause the trust to be treated as a corporation for U.S. federal income tax purposes or otherwise subject the trust to entity-level taxation. Specifically, the present U.S. federal income tax treatment of publicly traded partnerships, including the trust, or an investment in the trust units may be modified by administrative, legislative or judicial interpretation at any time. For example, at the federal level, legislation has been proposed in the past that would have eliminated partnership tax treatment for certain publicly traded partnerships. Although such legislation would not have applied to the trust as it was proposed, it could be reintroduced in a manner that does apply to the trust.

        The trust agreement provides that if a law is enacted or existing law is modified or interpreted in a manner that subjects the trust to taxation as a corporation or otherwise subjects it to entity-level taxation for U.S. federal income tax purposes, subordination threshold amounts, the incentive threshold amounts and the target distribution amounts may be adjusted to reflect the impact of that law on the trust.

         The trust may adopt or may have adopted positions that may not conform to all aspects of existing Treasury Regulations. If the IRS contests the tax positions the trust takes, the value of the trust units may be adversely affected, the cost of any IRS contest will reduce the trust's cash available for distribution and income, gains, losses and deductions may be reallocated among trust unitholders.

        If the IRS contests any of the U.S. federal income tax positions the trust takes or has taken, the value of the trust units may be adversely affected because the cost of any IRS contest will reduce the trust's cash available for distribution and income, gain, loss and deduction may be reallocated among trust unitholders. For example, the trust generally prorates its items of income, gain, loss and deduction between transferors and transferees of the trust units each quarter based upon the record ownership of the trust units on the quarterly record date in such quarter, instead of on the basis of the date a particular trust unit is transferred. Although simplifying conventions are contemplated by the Internal Revenue Code, and most publicly traded partnerships use similar simplifying conventions, the use of these methods may not be permitted under existing Treasury Regulations.

        The trust has not requested a ruling from the IRS with respect to its treatment as a partnership for U.S. federal income tax purposes or any other matter affecting the trust. The IRS may adopt positions that differ from the conclusions of SandRidge's counsel or from the positions the trust takes. It may be necessary to resort to administrative or court proceedings to attempt to sustain some or all of the conclusions of SandRidge's counsel expressed in this prospectus or the positions the trust takes.

Table of Contents

A court may not agree with some or all of the conclusions of SandRidge's counsel or positions the trust takes. Any contest with the IRS may materially and adversely impact the market for the trust units and the price at which they trade. In addition, the trust's costs of any contest with the IRS will be borne indirectly by the trust unitholders because the costs will reduce the trust's cash available for distribution.

         Each unitholder is required to pay taxes on the unitholder's share of the trust's income even if a unitholder does not receive cash distributions from the trust equal to the unitholder's share of the trust's taxable income.

        Because the trust unitholders are treated as partners to whom the trust allocates taxable income that could be different in amount than the cash the trust distributes, each unitholder may be required to pay any federal income taxes and, in some cases, state and local income taxes on the unitholder's share of the trust's taxable income even if a unitholder may not receive cash distributions from the trust equal to the unitholder's share of the trust's taxable income or even equal to the actual tax liability that results from that income.

         Tax gain or loss on the disposition of the trust units could be more or less than expected.

        If a unitholder sells its trust units, the unitholder will recognize a gain or loss equal to the difference between the amount realized and the unitholder's tax basis in those trust units. Because distributions in excess of a unitholder's allocable share of the trust's net taxable income decrease the unitholder's tax basis in its trust units, the amount, if any, of such prior excess distributions with respect to the trust units unitholders sell will, in effect, become taxable income to unitholders if unitholders sell such trust units at a price greater than the unitholder's tax basis in those trust units, even if the price the unitholder receives is less than the unitholder's original cost. Furthermore, a substantial portion of the amount realized, whether or not representing gain, may be taxed as ordinary income due to potential recapture items, including depletion recapture.

         The ownership and disposition of trust units by non-U.S. persons may result in adverse tax consequences to them.

        Investment in trust units by non-U.S. persons raises issues unique to them. For example, distributions to non-U.S. persons will be reduced by withholding taxes at the highest applicable effective tax rate, and non-U.S. persons may be required to file U.S. federal income tax returns and pay tax on their share of the trust's taxable income or proceeds from the sale of trust units. If a unitholder is a non-U.S. person, the unitholder should consult a tax advisor before investing in the trust units.

         The trust treats each purchaser of trust units as having the same economic attributes without regard to the actual trust units purchased. The IRS may challenge this treatment, which could adversely affect the value of the trust units.

        Due to a number of factors, including the trust's inability to match transferors and transferees of trust units, the trust may adopt positions that may not conform to all aspects of existing Treasury Regulations. A successful IRS challenge to those positions could adversely alter the tax effects of an investment in trust units. It also could affect the timing of tax benefits or the amount of gain from a unitholder's sale of trust units and could have a negative impact on the value of the trust units or result in audit adjustments to a unitholder's tax returns.

Table of Contents

         The trust prorates its items of income, gain, loss and deduction between transferors and transferees of the trust units each quarter based upon the record ownership of the trust units on the quarterly record date, in such quarter, instead of on the basis of the date a particular trust unit is transferred. The IRS may challenge this treatment, which could change the allocation of items of income, gain, loss and deduction among the trust unitholders.

        The trust generally prorates its items of income, gain, loss and deduction between transferors and transferees of the trust units based upon the record ownership of the trust units on the quarterly record date in such quarter instead of on the basis of the date a particular trust unit is transferred. The use of this proration method may not be permitted under existing Treasury Regulations, and, accordingly, SandRidge's counsel is unable to opine as to the validity of this method. If the IRS were to challenge the trust's proration method, the trust may be required to change its allocation of items of income, gain, loss and deduction among the trust unitholders and the costs to the trust of implementing and reporting under any such changed method may be significant.

         A trust unitholder whose trust units are loaned to a "short seller" to cover a short sale of trust units may be considered as having disposed of those trust units. If so, he would no longer be treated for tax purposes as a partner with respect to those trust units during the period of the loan and may recognize gain or loss from the disposition.

        Because a trust unitholder whose trust units are loaned to a "short seller" to cover a short sale of trust units may be considered as having disposed of the loaned trust units, he may no longer be treated for tax purposes as a partner with respect to those trust units during the period of the loan to the short seller and the unitholder may recognize gain or loss from such disposition. Moreover, during the period of the loan to the short seller, any of the trust's income, gains, losses or deductions with respect to those trust units may not be reportable by the unitholder and any cash distributions received by the unitholder as to those trust units could be fully taxable as ordinary income. SandRidge's counsel has not rendered an opinion regarding the treatment of a unitholder where trust units are loaned to a short seller to cover a short sale of trust units; therefore, trust unitholders desiring to assure their status as partners and avoid the risk of gain recognition from a loan to a short seller are urged to modify any applicable brokerage account agreements to prohibit their brokers from loaning their trust units.

         The trust may adopt certain valuation methodologies that may affect the income, gain, loss and deduction allocable to the trust unitholders. The IRS may challenge this treatment, which could adversely affect the value of the trust units.

        The U.S. federal income tax consequences of the ownership and disposition of trust units will depend in part on the trust's estimates of the relative fair market values, and the initial tax bases of the trust's assets. Although the trust may from time to time consult with professional appraisers regarding valuation matters, the trust will make many of the relative fair market value estimates itself. These estimates and determinations of basis are subject to challenge and will not be binding on the IRS or the courts. If the estimates of fair market value or basis are later found to be incorrect, the character and amount of items of income, gain, loss or deductions previously reported by trust unitholders might change, and trust unitholders might be required to adjust their tax liability for prior years and incur interest and penalties with respect to those adjustments.

         The sale or exchange of 50% or more of the trust's capital and profits interests during any 12-month period will result in the termination of the trust's partnership status for U.S. federal income tax purposes.

        The trust will be considered to have technically terminated for U.S. federal income tax purposes if there is a sale or exchange of 50% or more of the total interests in its capital and profits within a 12-month period. For purposes of determining whether the 50% threshold has been met, multiple sales of the same trust unit within any 12-month period will be counted only once. The trust's termination

Table of Contents

would, among other things, result in the closing of its taxable year for all trust unitholders, which would result in the trust filing two tax returns (and the trust unitholders would receive two Schedules K-1) for one calendar year. However, the IRS has announced a relief procedure whereby if a publicly traded partnership that has technically terminated requests and the IRS grants special relief, among other things, the partnership will be required to provide only a single Schedule K-1 to unitholders for the short taxable years that result from the technical termination. In the case of a unitholder reporting on a taxable year other than a calendar year ending December 31, the closing of the trust's taxable year as a result of any technical termination may also result in more than twelve months of the trust's taxable income being includable in his or her taxable income for the year of termination. A technical termination would not affect the trust's classification as a partnership for U.S. federal income tax purposes, but instead, the trust would be treated as a new partnership for tax purposes. If treated as a new partnership, the trust must make new tax elections and could be subject to penalties if the trust is unable to determine that a technical termination occurred.

         Certain U.S. federal income tax preferences currently available with respect to oil and natural gas production may be eliminated as a result of future legislation.

        In recent years, the Obama administration's budget proposals and other proposed legislation have included elimination of certain key U.S. federal income tax incentives currently applicable to oil and gas exploration and production activities. If enacted into law, these provisions would eliminate certain tax preferences applicable to taxpayers engaged in the exploration and production of natural resources. These changes include, but are not limited to (i) the repeal of the percentage depletion allowance for oil and gas properties, (ii) the elimination of current deductions for intangible drilling and development costs, (iii) the elimination of the deduction for U.S. production activities and (iv) the increase in the amortization period from two years to seven years for geophysical costs paid or incurred in connection with the exploration for or development of, oil and gas within the United States. It is unclear whether any such changes will be enacted and, if so, when any such changes would become effective.

Table of Contents

CAUTIONARY STATEMENT REGARDING FORWARD-LOOKING STATEMENTS

        This prospectus and the documents incorporated by reference herein contain forward-looking statements. Such forward-looking statements are based on assumptions and beliefs that the trust and SandRidge believe to be reasonable; however, assumed facts almost always vary from actual results, and the differences between assumed facts and actual results can be material, depending upon the circumstances. Where the trust or SandRidge expresses an expectation or belief as to future results, that expectation or belief is expressed in good faith and based on assumptions believed to have a reasonable basis. It cannot be assured, however, that the stated expectation or belief will occur or be achieved or accomplished. All statements other than statements of historical facts included or incorporated by reference in this prospectus, including, without limitation, statements regarding the trust's proved oil, including natural gas liquids, and natural gas reserves, the trust's or SandRidge's future financial position, business strategy, budgets, pending acquisitions, recent acquisitions and divestitures, project costs and plans and objectives for future operations, including the information under the heading "Target Distributions and Subordination and Incentive Thresholds," statements pertaining to future development activities and costs, and other statements in this prospectus that are prospective and constitute forward-looking statements are forward-looking statements.

        The words "estimate," "assume," "target," "project," "predict," "believe," "expect," "anticipate," "potential," "could," "may," "foresee," "plan," "goal," "should" and "intend" and similar expressions will generally identify forward-looking statements. Forward-looking statements, whether written or oral, are expressly qualified by these cautionary statements and any other cautionary statements that may accompany those statements. In addition, neither the trust nor SandRidge undertakes an obligation to update or revise any forward-looking statements to reflect events or circumstances after the date of this prospectus.

        With this in mind, you should consider the risks discussed under the heading "Risk Factors" in this prospectus, as well as any risks discussed in any prospectus supplement and those contained in each of SandRidge's and the trust's Annual Report on Form 10-K for the year ended December 31, 2011, each of SandRidge's and the trust's Quarterly Reports on Form 10-Q for the quarters ended March 31 and June 30, 2012 and other disclosures about SandRidge and the trust that are included in or incorporated by reference into this prospectus. See "Where You Can Find More Information."

Table of Contents

USE OF PROCEEDS

        The selling unitholder is offering all of the common units to be sold pursuant to this prospectus. Accordingly, the trust will not receive any of the proceeds received from the sale of the common units. The selling unitholder intends to use the proceeds received from the sale of the common units for general corporate purposes, which may include funding of capital expenditures.

Table of Contents

SANDRIDGE ENERGY, INC.

        SandRidge is an independent oil and natural gas company concentrating on development and production activities related to the exploitation of its significant holdings in the Mid-Continent area of Oklahoma and Kansas and in the Permian Basin in west Texas as well as in the Gulf of Mexico, West Texas Overthrust and Gulf Coast. SandRidge also operates businesses that are complementary to its primary development and production activities, including gas gathering and processing facilities, an oil and natural gas marketing business and an oil field services business, including its wholly owned drilling rig business. SandRidge also captures and transports CO₂ to the Permian Basin for use in tertiary recovery projects.

        SandRidge's principal executive offices are located at 123 Robert S. Kerr Avenue, Oklahoma City, Oklahoma 73102 and its telephone number is (405) 429-5500. Its website is http://www.sandridgeenergy.com.

        The trust units do not represent interests in or obligations of SandRidge.

Table of Contents

TARGET DISTRIBUTIONS AND SUBORDINATION AND INCENTIVE THRESHOLDS

        SandRidge has conveyed to the trust Royalty Interests in specified oil and natural gas properties in the AMI. The Royalty Interests in the Initial Wells (the "PDP Royalty Interest") entitle the trust to receive 90% of the proceeds (exclusive of any production or development costs but 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 the Initial Wells. The Royalty Interests in the Trust Development Wells (the "Development Royalty Interest") entitle the trust to receive 50% of the proceeds (exclusive of any production or development costs but after deducting post-production costs and any applicable taxes) from the sale of production of oil and natural gas attributable to SandRidge's net revenue interest in the Trust Development Wells.

        The amount of trust revenues and cash distributions to trust unitholders depends on:

•

the timing of initial production from the Trust Development Wells;



•

prices received for oil, including natural gas liquids, and natural gas;



•

the volume of oil, including natural gas liquids, and natural gas produced and sold;



•

amounts realized and paid under hedging arrangements;



•

post-production costs and any applicable taxes; and



•

the trust's general and administrative expenses.

        At the time of the trust's initial public offering, SandRidge calculated quarterly target levels of cash distributions for the life of the trust. Such target distributions are set forth on Schedule 1 to the trust agreement, which is incorporated herein by reference to Exhibit 4.1 to the registration statement of which this prospectus forms a part. The target distributions

Authorized Capitalization

Our authorized capital stock consists of 300,000,000 shares, which include 250,000,000 shares of common stock, par value $0.001 par value per share (the “common stock”) and 50,000,000 shares of preferred stock, par value $0.001 per share (the “preferred stock”).

As of June 30, 2022, there were prepared by SandRidge on a cash basis based on assumptionsapproximately 36,741,824 issued and outstanding shares of production volumes, pricingcommon stock and other assumptions thatno shares of preferred stock issued and outstanding. All of the shares of common stock are described below in "—Significant Assumptions Used to Calculate the Target Distributions." Actual cash distributions may vary from the target distributions set forth on Schedule 1duly authorized, validly issued, fully paid and non-assessable. Pursuant to the trust agreement.Bylaws and subject to any resolution of the stockholders, the Board is authorized to issue any of our authorized but unissued capital stock.

        SandRidge paysCommon Stock

Dividends

Subject to the trustrights granted to any holders of the preferred stock, holders of the common stock will be entitled to dividends in the amounts and at the times declared by our Board in our discretion out of any assets or our funds legally available for the payment of dividends.

Voting

Each holder of shares of the common stock is entitled to one vote for each quarter an amount equalshare of the common stock on all matters presented to our stockholders (including the election of directors). Our common stock does not have cumulative voting rights. Uncontested elections of directors are decided by a majority of the votes cast with respect to that director’s election, and contested elections of directors are decided by a plurality of the votes cast present in person or represented by proxy,

Liquidation

The holders of the common stock will share equally and ratably in our assets on liquidation after payment or provision for all liabilities and any preferential liquidation rights of any preferred stock then outstanding.

Other Rights

The holders of the common stock do not have preemptive rights to purchase shares of our common stock. The common stock is not convertible, redeemable, assessable or entitled to the Royalty Interestsbenefits of any sinking or repurchase fund. The rights, preferences and privileges of holders of the common stock will be subject to those of the holders of any shares of preferred stock that we may issue in the proceedsfuture.

Under the terms of productionthe Certificate of Incorporation and the Bylaws, we are prohibited from issuing any non-voting equity securities to the Underlying Properties received duringextent required under Section 1123(a)(6) of the calendar quarter most recently ended (after deducting post-production costsBankruptcy Code and anyonly for so long as Section 1123 of the Bankruptcy Code is in effect and applicable taxes). The trust,to us.

Table of Contents

distribution level for the corresponding quarter. In exchange for agreeing to subordinate these 7,000,000 trust units, and in order to provide additional financial incentive to SandRidge to perform its drilling obligation and operations on the Underlying Properties in an efficient and cost-effective manner, 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 during the subordination period exceeds the target distribution for such quarter by more than 20%. SandRidge's right to receive incentive distributions terminates upon the expiration of the subordination period.

        The subordinated units automatically convert into common units on a one-for-one basis and SandRidge's right to receive incentive distributions terminates at the end of the fourth full calendar quarter following SandRidge's satisfaction of its drilling obligation to the trust. SandRidge currently expectsbylaw provides that it will complete its drilling obligation onmay not be amended, repealed, or before December 31, 2014 and that, accordingly, the subordinated units will convert into common units on or before December 31, 2015. SandRidge is obligated to complete its drilling obligation by December 31, 2015, in which event the subordinated units would convert into common units on or before December 31, 2016.

At the time of the trust's initial public offering, SandRidge's management prepared the prospective financial information set forth below to present the target distributions to the holders of the trust units based on the estimates and assumptions described below. The accompanying prospective financial information was not prepared with a view toward complying with the guidelines of the SEC or the guidelines establishedreadopted by the American InstituteBoard of Certified Public Accountants with respect to preparation and presentationDirectors. The Certificate of prospective financial information. More specifically, such information omits itemsIncorporation also provides that are not relevant tothat the trust. The prospective financial information was based on estimates and judgments at the time of the trust's initial public offering of common units, and readers of this prospectus are cautioned not to place undue reliance on such information.

The prospective financial information set forth below was prepared by, and was the responsibility of, SandRidge's management. PricewaterhouseCoopers LLP, the trust's and SandRidge's independent registered public accountant, has not examined, compiled or performed any procedures with respect to the accompanying prospective financial information and, accordingly, PricewaterhouseCoopers LLP expresses no opinion or any other form of assurance with respect thereto. The reports of PricewaterhouseCoopers LLP incorporated by reference into this prospectus do not extend to the prospective financial information and shouldBylaws may not be read to do so.

Table of Contents

        The following table sets forth the target distributions and subordination and incentive thresholds for each calendar quarter through the fourth quarter of 2016.

        The projections and assumptions on which the target distributions were based are subject to significant uncertainties, many of which are beyond the control of SandRidge and the trust.Actual cash distributions to trust unitholders, therefore, could vary significantly based upon eventsadopted, amended, restated or conditions occurring that are different from the events or conditions assumed to occur for purposes of creating the target distributions set forth in the table above and incorporated by reference into this prospectus.

        Cash distributions to trust unitholders are particularly sensitive to fluctuations in prices for and production volumes of oil, including natural gas liquids, and natural gas. As a result of typical production declines for oil and natural gas properties, production estimates generally decrease from year to year. However, the production estimates used to establish the target distributions reflect that these declines are expected to be offset by additional production from Trust Development Wells as they are completed and begin to produce. The timing of the completion of, and the amount of production attributable to, the Trust Development Wells are substantially dependent on SandRidge executing its drilling plans with respect to the drilling and completion of the Trust Development Wells in a manner substantially similar to those underlying the assumptions used in establishing these target distributions. In addition, the completion of SandRidge's drilling obligation will depend, in part, on the completion of drilling for certain Trust Development Wells by third parties, over whom SandRidge has no control,

Table of Contents

in a manner consistent with the assumptions used in establishing these target distributions. Please see "Risk Factors" for risks relating to the timing of drilling and amount of production attributable to the Trust Development Wells.As a result of these factors, the target distributions shown in the table above and incorporated by reference into this prospectus are not necessarily indicative of distributions for future years.

Significant Assumptions Used to Calculate the Target Distributions

        The target distributions and subordination and incentive thresholds set forth above and incorporated by reference into this prospectus were calculated at the time of the trust's initial public offering in April 2011. At that time, assumptions about the revenues and expenses of the trust were calculated based on the terms of the conveyances creating the Royalty Interests using the following assumptions and those set forth elsewhere in this section, "Target Distributions and Subordination and Incentive Thresholds." For more information about the trust's Royalty Interests, please see "Description of the Royalty Interests."

There can be no assurance regarding the accuracy of the assumptions used to calculate the target distributions and subordination and incentive thresholds, including the production estimates, prices of oil and natural gas or any other assumptions set forth in this "—Significant Assumptions Used to Calculate the Target Distributions."

        Production Estimates.    Other than January 2011 and February 2011 production, which were based on actual realized productionrepealed by the Underlying Properties, production estimates for each of the quarters during the life of the trust were based on the reserve report prepared for the truststockholders except by Netherland Sewell as of December 31, 2010. The estimates of reserves and production relating to the Underlying Properties and the Royalty Interests included in such reserve report were made in accordance with the SEC's rules for reserve reporting.

        The estimated production in the forecast period gave effect to the assumed drilling and completion by SandRidge of approximately 31 Trust Development Wells per year during the four-year drilling period, and the completion by SandRidge of its drilling obligation to the trust of 123 Trust Development Wells by December 31, 2014.

        See "—Oil Prices" and "—Natural Gas Prices" below for a description of changes in production due to price variations. Differing levels of production will result in different levels of distributions and cash returns. If oil and natural gas prices decline, the operators of producing oil and natural gas properties may elect to reduce or completely suspend production. No adjustments were made to estimated production to reflect potential reductions or suspensions of production by SandRidge or third party operators.

        Oil Prices.    The assumed oil prices utilized for purposes of preparing the target distributions were based on settled NYMEX prices for January, February and March 2011 and NYMEX forward pricing for the 33-month period ending December 31, 2013 and assumed price increases thereafter of 2.5% annually, capped at $120.00 per Bbl. Using these assumptions, the price per Bbl for oil was assumed to

Table of Contents

reach its cap in 2025. The table below sets forth NYMEX forward pricing as of March 18, 2011 for the 18-month period ending December 31, 2013.

Estimated Market Prices for Oil ($/Bbl)
Based on Settled NYMEX Pricing as of March 18, 2011

        Natural Gas Prices.    The assumed natural gas prices utilized for purposes of preparing the target distributions were based on settled NYMEX prices for January, February and March 2011 and NYMEX forward pricing for the 33-month period ending December 31, 2013 and assumed price increases thereafter of 2.5% annually, capped at $7.00 per MMBtu. Using these assumptions, the price per MMBtu for natural gas was assumed to reach its cap in 2022. The table below sets forth NYMEX forward pricing as of March 18, 2011 for the 18-month period ending December 31, 2013.

Estimated Market Prices for Natural Gas ($/MMBtu)
Based on Settled NYMEX Pricing as of March 18, 2011

        In April 2011, SandRidge entered into a derivatives agreement with the trust in order to transfer to the trust the effect of certain hedge contracts entered into between SandRidge and third parties. It was assumed that pursuant to such agreement, approximately 54% of the expected production and approximately 60% of the expected revenues upon which the target distributions were based from April 1, 2011 through December 31, 2015 would be hedged.

Table of Contents

        Differentials.    Proceeds to the trust are calculated based on the actual price realized by SandRidge for oil and natural gas produced, which differs from NYMEX prices as a result of:

•

discounts based on location,



•

quality of oil and natural gas produced,



•

estimated shrinkage and fuel usage for natural gas and



•

post-production costs (generally consisting of costs incurred to gather, store, compress, transport, process, treat, dehydrate and market the oil and natural gas produced).

We refer to these charges collectively as pricing "differentials" from NYMEX pricing.

        To prepare the target distributions, assumed differentials were subtracted from the NYMEX prices shown in the tables above, based on an analysis by SandRidge of historical realized prices for production from the region. The estimated realized prices for natural gas assumed a 19% negative differential from the NYMEX futures price for natural gas and an estimated 1.13 times conversion factor from MMBtu to Mcf, which accounted for the historical volatility in differentials in the region.

        The estimated realized prices for oil assumed a $5.00 per barrel negative differential from the NYMEX futures price for oil based on the historical stability of the differential and the estimated gravity of the oil in the reserve report prepared for the trust by Netherland Sewell as of December 31, 2010, which varies from sweet to sour crude oil. The reserve report prepared for the trust by Netherland Sewell as of December 31, 2010 classified 72% and 28% of the oil production over the life of the trust as sweet crude and sour crude, respectively. Due to the higher refining costs of sour crude oil, it typically has a greater differential than sweet crude oil. Over the eleven months ended November 30, 2010, SandRidge realized a price differential to NYMEX prices for sweet crude oil of $3.31 per barrel and a price differential to NYMEX prices for sour crude oil of $9.20 per barrel. The assumed $5.00 per barrel differential approximated the weighted average of SandRidge's actual differentials for sweet and sour crude oil over this eleven month period. A flat dollar differential amount was chosen because the realized oil differential has historically been stable for oil produced in the mid-continent region.

        There can be no assurance that realized prices in the future will be the same as historical realized prices or the assumed realized prices used to prepare the target distributions.

        Administrative Expense.    Trust administrative expenses per year were estimated to be approximately $900,000, although such costs could be greater or less depending on future events that cannot be predicted. Included in this annual estimate, among other miscellaneous items, were annual administrative fees of $150,000 for the trustee, $2,300 for the Delaware trustee and $200,000 for SandRidge, respectively. It was also assumed that the annual fee to SandRidge would remain flat for the life of the trust, while the remaining estimated costs ($700,000) would escalate at a rate of 2.5% annually starting in the second quarter of 2012. It was also assumed that the trust would pay, out of the first cash payment received by the trust, the trustee's and Delaware trustee's legal expenses incurred in forming the trust as well as the trustee's acceptance fee in the amount of $10,000, and that such costs would be deducted by the trust before distributions were made to trust unitholders.

        Trustee's Cash Reserve.    It was assumed that the trustee would withhold $1.0 million from the first distribution to unitholders to establish a cash reserve available for potential administrative expenses of the trust. No other cash reserves were assumed.

        Tax Treatment of Royalty Interests.    For U.S. federal income tax purposes, the portion of the Royalty Interests with a 20-year term should be treated as debt instruments and, accordingly, were assumed to be subject to the original issue discount, or OID, rules of the Internal Revenue Code, which require that payments made to the trust with respect to such royalties be treated first as

Table of Contents

consisting of a payment of interest to the extent of interest deemed accrued under the OID rules at the applicable federal rate and the excess, if any, be treated as a payment of principal (which is non-taxable). For U.S. federal income tax purposes, the portion of the Royalty Interests that are perpetual either will be or should be treated as mineral royalty interests, which give rise to ordinary income subject to depletion.

        Timing of Actual Cash Distributions.    Quarterly cash distributions are made on or about the 60th day following the end of each calendar quarter to unitholders of record on or about the 45th day following each calendar quarter. Due to the timing of SandRidge's receipt of cash for production, it was assumed that cash distributions for each quarter would include production from the first two months of the quarter just ended as well as the last month of the immediately preceding quarter.

        Applicable Taxes.    Oklahoma levies a tax on the production of oil and natural gas within the state of Oklahoma. At the time these assumptions were made, a reduced rate of production tax was available for the first four years of a horizontal well's production so long as the well was producing before July 1, 2015. Accordingly, it was assumed that the effective rate of production tax on the oil and gas attributable to the trust would be approximately 1.0% for the first four years of production for each well, and approximately 7.0% thereafter.

        Incentive Distributions.    To the extent that the trust has cash available for distribution in excess of the incentive thresholds during the subordination period, SandRidge will be entitled to receive 50% of such cash as incentive distributions. The incentive distributions terminate upon completion of the subordination period.

Table of Contents

DESCRIPTION OF THE ROYALTY INTERESTS

        The Royalty Interests were conveyed to the trust by SandRidge by means of conveyance instruments that were recorded in the appropriate real property records in the counties where the oil and natural gas properties to which the Underlying Properties relate are located.

        The Royalty Interests were conveyed from SandRidge's interest in the Initial Wells and the Trust Development Wells. The PDP Royalty Interest entitles the trust to receive 90% of the proceeds (exclusive of any production or development costs but after deducting post-production costs and any applicable taxes) from the sale of production of oil, including natural gas liquids, and natural gas attributable to SandRidge's net revenue interest in the Initial Wells. The Development Royalty Interest entitles the trust to receive 50% of the proceeds (exclusive of any production or development costs but after deducting post-production costs and any applicable taxes) from the sale of production of oil, including natural gas liquids, and natural gas attributable to SandRidge's net revenue interest in the Trust Development Wells.

        The PDP Royalty Interest consists of a term royalty interest entitling the trust to receive 45% of the proceeds from the sale of oil, including natural gas liquids, and natural gas production attributable to SandRidge's net revenue interest in the Initial Wells (after deducting post-production costs and any applicable taxes) for a period of 20 years commencing on January 1, 2011 (the "Term PDP Royalty") and a perpetual royalty interest entitling the trust to receive 45% of the proceeds from the sale of oil, including natural gas liquids, and natural gas production attributable to SandRidge's net revenue interest in the Initial Wells (after deducting post-production costs and any applicable taxes) (the "Perpetual PDP Royalty").

        The Development Royalty Interest consists of a term royalty interest entitling the trust to receive 25% of the proceeds from the sale of the production of oil, including natural gas liquids, and natural gas attributable to SandRidge's net revenue interest in the Trust Development Wells (after deducting post-production costs and any applicable taxes) for a period of 20 years commencing on January 1, 2011 (the "Term Development Royalty") and a perpetual royalty interest entitling the trust to receive 25% of the proceeds from the sale of oil, including natural gas liquids, and natural gas production attributable to SandRidge's net revenue interest in the Trust Development Wells (after deducting post-production costs and any applicable taxes) (the "Perpetual Development Royalty").

        The Term PDP Royalty and the Term Development Royalty are collectively referred to as the "Term Royalties," while the Perpetual PDP Royalty and the Perpetual Development Royalty are collectively referred to as the "Perpetual Royalties."

        The percentage of production proceeds received by the trust with respect to a well equals the product of (i) the percentage of proceeds to which the trust is entitled under the terms of the conveyances (90% for the Initial Wells and 50% for the Trust Development Wells) multiplied by (ii) SandRidge's net revenue interest in the well. SandRidge on average owns a 56.3% net revenue interest in the Initial Wells, a 64.0% net revenue interest in the Trust Development Wells drilled and completed as of June 30, 2012 and a 57.0% net revenue interest in the properties in the AMI on which it intends to drill the Remaining Development Wells. SandRidge's actual net revenue interest in any particular Remaining Development Well may differ from the average net revenue interest SandRidge owns in the properties in the AMI, and depends on SandRidge's working interest and the royalty interests and similar revenue burdens owed to third parties with respect to such well.

PDP Royalty Interest

        The PDP Royalty Interest entitles the trust to receive an amount of cash for each calendar quarter equal to 90% of the proceeds (exclusive of any production or development costs but after deducting post-production costs and any applicable taxes) from the sale of oil, including natural gas liquids, and

Table of Contents

natural gas production attributable to SandRidge's net revenue interest in the Initial Wells. Proceeds from the sale of oil, including natural gas liquids, and natural gas production attributable to SandRidge's net revenue interest in the Initial Wells in any calendar quarter means, for any calendar quarter commencing on or after January 1, 2011, the amount calculated based on actual production volumes attributable to SandRidge's net revenue interest in the Initial Wells, in each case after deducting the trust's proportionate share of:

•

any taxes levied on the severance or production of the oil, including natural gas liquids, and natural gas produced from the Initial Wells and any property taxes attributable to the oil, including natural gas liquids, and natural gas produced from the Initial Wells, and any taxes associated with facilities, equipment, land or other property associated with the Initial Wells; and



•

post-production costs, which generally consist of costs incurred to gather, store, compress, transport, process, treat, dehydrate and market the oil, including natural gas liquids, and natural gas produced, as applicable (excluding costs for marketing services provided by SandRidge).

        Proceeds payable to the trust from the sale of oil, including natural gas liquids, and natural gas production attributable to the Initial Wells in any calendar quarter are not subject to any deductions for any expenses attributable to exploration, drilling, development, operating, maintenance or any other costs incident to the production of oil, including natural gas liquids, and natural gas production attributable to the Initial Wells, including any costs to plug and abandon an Initial Well.

Development Royalty Interest

        The Development Royalty Interest entitles the trust to receive an amount of cash for each calendar quarter equal to 50% of the proceeds (exclusive of any production or development costs but after deducting post-production costs and any applicable taxes) from the sale of estimated oil, including natural gas liquids, and natural gas production attributable to SandRidge's net revenue interest in the Trust Development Wells. Proceeds from the sale of oil, including natural gas liquids, and natural gas production attributable to SandRidge's net revenue interest in the Trust Development Wells in any calendar quarter means, for any calendar quarter commencing on or after January 1, 2011, the amount calculated based on actual production volumes attributable to SandRidge's net revenue interest in the Trust Development Wells, in each case after deducting the trust's proportionate share of:

•

any taxes levied on the severance or production of the oil, including natural gas liquids, and natural gas produced from the Trust Development Wells and any property taxes attributable to the oil, including natural gas liquids, and natural gas produced from the Trust Development Wells, and any taxes associated with facilities, equipment, land or other property associated with the Trust Development Wells; and



•

post-production costs, which generally consist of costs incurred to gather, store, compress, transport, process, treat, dehydrate and market the oil, including natural gas liquids, and natural gas produced, as applicable (excluding costs for marketing services provided by SandRidge).

        Proceeds payable to the trust from the sale of oil, including natural gas liquids, and natural gas production attributable to the Trust Development Wells in any calendar quarter are not subject to any deductions for any expenses attributable to exploration, drilling, development, operating, maintenance or any other costs incident to the production of oil, including natural gas liquids, and natural gas production attributable to the Trust Development Wells, including any costs to drill a Trust Development Well.

Sale of the Perpetual Royalties

        The trust will begin to liquidate on December 31, 2030 (the "Termination Date") and will soon thereafter wind up its affairs and terminate. The Term Royalties automatically revert to SandRidge at

Table of Contents

the Termination Date, while the Perpetual Royalties will be sold and the proceeds thereof will be distributed to the unitholders at the Termination Date or soon thereafter. SandRidge has a first right of refusal to purchase the Perpetual Royalties at the Termination Date.

        The trust agreement provides that the trustee must use commercially reasonable efforts to retain a third-party advisor to market the Perpetual Royalties within 30 business days of the Termination Date. If the trustee receives a bona fide offer from a proposed purchaser other than SandRidge and wants to sell all or part of the Perpetual Royalties, it is required to give notice (the "Offer Notice") to SandRidge, identifying the proposed purchaser and setting forth the proposed sale price, payment terms and other material terms and conditions under which the trustee is proposing to sell. SandRidge would then have 30 days from receipt of the Offer Notice to elect, by notice to the trustee, to purchase the subject properties offered for sale on the terms and conditions set forth in the Offer Notice. If SandRidge makes such election, the proposed purchaser would be entitled to receive reimbursement of its reasonable and documented expenses incurred in connection with its review and analysis of the subject properties and bid preparation. SandRidge and the trust would share equally the cost of reimbursement to the proposed purchaser.

        If SandRidge does not give notice within the 30-day period following the Offer Notice, the trustee may sell such properties to the identified purchaser on terms and conditions that are substantially the same as those previously set forth in such Offer Notice. Moreover, if, after a reasonable marketing period, no bid is received on any or all of the Perpetual Royalties from any party other than SandRidge, then SandRidge shall obtain, at the trust's expense, and deliver to the trustee, a fairness opinion from a nationally-recognized valuation firm with expertise in valuing oil and natural gas properties stating that the proposed sale price to be paid by SandRidge to the trust for the properties is fair to the trust.

Additional Features of the Royalty Interests

        Reasonably Prudent Operator Standard.    Under the conveyances, SandRidge is obligated to act in good faith and as a reasonably prudent operator in the AMI under the same or similar circumstances as it would if it were acting with respect to its own properties, disregarding the existence of the Royalty Interests as burdens affecting such properties.

        Warranty and Remedies.    In the conveyances, SandRidge warrants to the trust that the Royalty Interests granted to the trust are free of all encumbrances created by, through or under SandRidge (other than certain permitted encumbrances). If this warranty is breached, SandRidge must add to amounts owed to the trust the difference between what the trust actually receives from the Royalty Interests and what the trust should have received from the Royalty Interests had this warranty not been breached. If SandRidge's net revenue interest with respect to the Underlying Properties ever proves to be larger as of the effective date of a conveyance than the amount reflected in the conveyance at the time of grant, and, as a result, the trust receives amounts greater than what the trust would have received if the correct net revenue interest had been reflected in the conveyance, SandRidge has the right to treat any such amounts paid to the trust as a credit or offset against any amounts payable to the trust on account of a breach of the warranty described above.

        Controversies.    If a controversy arises as to the sales price of any production, then for purposes of determining gross proceeds:

•

amounts withheld or placed in escrow by a purchaser are not considered to be received by the owner of the underlying property until actually collected;



•

amounts received by the owner of the underlying property and promptly deposited with a nonaffiliated escrow agent will not be considered to have been received until disbursed to it by the escrow agent; and



•

amounts received by the owner of the underlying property and not deposited with an escrow agent will be considered to have been received.

Table of Contents

        Overpayments.    The trustee is not obligated to return any cash received from the Royalty Interests. Any overpayments made to the trust by SandRidge due to adjustments to prior calculations of proceeds or otherwise will reduce future amounts payable to the trust until SandRidge recovers the overpayments.

        Sale and Release of Underlying Properties.    The conveyances provide that SandRidge may not sell any of the Underlying Properties subject to the Royalty Interests until it has satisfied the drilling obligation pursuant to the terms of the development agreement. After the satisfaction of its drilling obligation, the conveyances generally permit SandRidge to sell, without the consent or approval of the trust unitholders, all or any part of its retained interest in the Underlying Properties, if such Underlying Properties are sold subject to and burdened by the Royalty Interests. The trust unitholders are not entitled to any proceeds of any sale of SandRidge's interest in the Underlying Properties that remains subject to and burdened by the Royalty Interests. Following such sale, the royalties attributable to the transferred property will be calculated as described in this prospectus, and paid by the purchaser or transferee to the trust. As a result, any additional costs resulting from the sold property will not reduce the proceeds paid to the trust from the Underlying Properties retained by SandRidge. SandRidge will require any purchaser of any of the Underlying Properties to enter into an agreement to perform SandRidge's obligations under the administrative services agreement with respect to those properties under the same terms and conditions.

        In addition, following the satisfaction of its drilling obligation, SandRidge may, without the consent of the trust unitholders, require the trust to release for sale royalty interests with an aggregate value to the trust not to exceed $5.0 million during any 12-month period. These releases will be made only in connection with a sale by SandRidge of a portion of the Underlying Properties and are conditioned upon the trust receiving an amount equal to the fair value to the trust of such royalty interests. Any net sales proceeds paid to the trust in respect of any such released Underlying Properties are distributable to trust unitholders for the quarter in which they are received. SandRidge has not identified for sale any of the Underlying Properties.

        Exchange and Addition of Acreage.    SandRidge may at its option at any time prior to the completion of its drilling obligation, cause the trust to exchange leased acreage subject to the Royalty Interests, free and clear of such Royalty Interests, for other leased acreage in the AMI, and cause such leased acreage exchanged to the trust to be made subject to the Royalty Interests as set forth in the conveyances (excluding any wells that are already producing on such leased acreage at the time of such exchange). Following such an exchange, any exchange acreage outside the AMI will be included in the AMI for all purposes of the development agreement, and the corresponding acreage in the AMI exchanged therewith will be excluded from the AMI for all purposes of the development agreement. In addition, in the event SandRidge acquires any additional leases or interests in the AMI (other than renewals or extensions) prior to the completion of its drilling obligation, SandRidge may at its option make such additional leases or interests subject to the Royalty Interests. In no event, however, may any exchange of acreage or any addition of leased acreage or interests be effected unless SandRidge certifies to the trust that, among other things, all of the aggregate acreage attributable to the exchanged leases or additional leases or interests shall not exceed five percent of the acreage initially subject to the Royalty Interests and that, with respect to exchange acreage, the reasonable quantity of proved undeveloped reserves and probable reserves of such exchange acreage does not differ significantly from the reasonable quantity of proved undeveloped reserves and probable reserves being exchanged for such acreage, and, with respect to additional leases or interests, the reserve profile of such acreage is consistent with the reserve profile of the acreage that would be developed in the absence of such additional acreage.

        Abandonment of Underlying Property.    SandRidge or any transferee of an Underlying Property has the right to abandon any well or property if it reasonably believes the well or property ceases to

Table of Contents

produce or is not capable of producing in commercially paying quantities. In making such decisions, SandRidge or any transferee of an Underlying Property is required under the applicable conveyance to act as a reasonably prudent operator in the AMI under the same or similar circumstances would act if it were acting with respect to its own properties, disregarding the existence of the Royalty Interests as burdens affecting such properties. Upon termination of the lease, that portion of the Royalty Interests derived from the terminated lease will be extinguished.

        Maintenance of Books and Records.    SandRidge must maintain books and records sufficient to determine the amounts payable for the Royalty Interests to the trust. Quarterly and annually, SandRidge must deliver to the trustee a statement of the computation of the proceeds for each computation period as well as quarterly drilling and production results.

        Reservation of Rights.    Pursuant to the conveyances, SandRidge expressly excepted and reserved all right, title and interest in and to any well and appurtenant production facilities not expressly conveyed to the trust.

Table of Contents

DESCRIPTION OF THE TRUST AGREEMENT

Creation and Organization of the Trust; Amendments

        The trust was created under Delaware law as a separate legal entity to acquire and hold the Royalty Interests for the benefit of the trust unitholders pursuant to a trust agreement between SandRidge, the trustee and the Delaware trustee. The Royalty Interests are passive in nature and none of the trust, the trustee or the Delaware trustee has any control over, or responsibility for, the operation of the Underlying Properties or the costs thereof. Neither SandRidge nor any other operator of the Underlying Properties has any contractual commitments to the trust to provide additional funding or to conduct further drilling on or to maintain its ownership interest in any of these properties other than the obligations of SandRidge to designate and drill the Trust Development Wells. However, SandRidge retains an interest in each of the Underlying Properties.

        The trust agreement provides that the trust's activities are generally limited to owning the Royalty Interests and other activities reasonably related thereto, including activities required or permitted by the terms of the conveyances related to the Royalty Interests and the derivatives agreement with SandRidge. As a result, the trust is not permitted to acquire other oil and natural gas properties or royalty interests. Additionally, the trust is not able to issue any additional trust units.

        The beneficial interests in the trust are divided into 28,000,000 trust units. Each trust unit represents an equal undivided beneficial interest in the property of the trust. Please read "Description of the Trust Units" for additional information concerning the trust units.

        Amendment of the trust agreement generally requires the vote of holders of a majority in voting power of the trust units andoutstanding shares of stock entitled to vote, voting together as a single class.

Special Meeting of Stockholders

Our Certificate of Incorporation provides that a special meeting of our stockholders may be called only by the Chief Executive Officer, the Chairman of the Board of Directors, the Board of Directors pursuant to a resolution adopted by a majority of the common units (excluding common units owned by SandRidge and its affiliates) voting in persontotal number of directors that the Corporation would have if there were no vacancies or by proxythe Secretary of the Corporation at a meetingthe written request or requests of such unitholdersholders of record of at which a quorum is present. At any time that SandRidge and its affiliates collectively own less than 10%least twenty-five percent (25%) of the voting power of the outstanding trust units; however,capital stock entitled to vote at the standard for approvaltime of such written request pursuant to the procedures set forth in the Bylaws.

Limits on Ability of Stockholders to Act by Written Consent

Our Bylaws provide that any action required or permitted to be taken at any annual or special meeting of stockholders may be taken only upon the vote of stockholders at an annual or special meeting duly noticed and called in accordance with the Bylaws, the Certificate of Incorporation, and the DGCL and may not be taken by written consent of the stockholders without a meeting.

Annual Meetings and Election of Directors

Our Certificate of Incorporation provides that our stockholders may act at an annual meeting of stockholders. The Certificate of Incorporation provides that the initial number of directors will be five and that the Board has the right to elect a number of directors to be designated as directors. A vacancy on the Board may be filled by a vote of a majority of the trust units, including units owned by SandRidge, votingdirectors in person or by proxy atoffice, and a meetingdirector appointed to fill a vacancy serves for the remainder of the unitholders at which a quorum is present. Abstentions and broker non-votes shall not be deemed to be a vote cast. However, no amendment may:

•

increase the powerterm of the trustee to engagedirector in business or investment activities;



•

decrease the incentive threshold or increase the subordination threshold or change the portion of the quarterly cash distributions payable as an incentive distribution;



•

alter the rights of the trust unitholders as among themselves; or



•

permit the trustee to distribute the Royalty Interests in kind.

        Amendments to the trust agreement's provisions addressing the following matters may not be made without SandRidge's consent:

•

dispositions of the trust's assets;



•

indemnification of the trustee;



•

reimbursement of out-of-pocket expenses of SandRidge when acting as the trust's agent;



•

termination of the trust; and



•

amendments of the trust agreement.

        Certain amendments to the trust agreement do not require the vote of the trust unitholders. See "—Permitted Amendments."

Table of Contents

        The business and affairs of the trust are managed by the trustee. The trustee has no ability to manage or influence the operation of the Underlying Properties. Although SandRidge operates a substantial number of the properties from which the trust obtains royalties, SandRidge hasvacancy occurred.

Limitation on Liability of Directors and Officers

Our Certificate of Incorporation provides that no abilitydirector shall be personally liable to manageus or influence the managementour stockholders for monetary damages for breach of the trust, except through its limited voting rightsfiduciary duty as a holder of trust units.

Assets of the Trust

        The principal assets of the trust consist of the PDP Royalty Interest and the Development Royalty Interest, and any cash and temporary investments being held for the payment of expenses and liabilities and for distributiondirector to the trust unitholders, as well as the trust's rights under its contractual arrangements, including the development agreement, the Drilling Support Lien, the administrative services agreement, and the derivatives agreement.

Duties and Powers of the Trustee; Liability of the Trustee

        The duties and powers of the trustee are specified in the trust agreement and by the laws of the State of Delaware, except as modified by the trust agreement. The trust agreement provides that the trustee shall not have any duties or liabilities, including fiduciary duties, except as expressly set forth in the trust agreement and the duties and liabilities of the trustee as set forth in the trust agreement replace any other duties and liabilities, including fiduciary duties, to which the trustee might otherwise be subject.

        The trustee's principal duties consist of:

•

collecting cash proceeds attributable to the Royalty Interests;



•

paying expenses, charges and obligations of the trust from the trust's assets;



•

receiving and making payments under the derivatives agreement with SandRidge;



•

determining whether cash distributions exceed subordination or incentive thresholds, and making cash distributions to the unitholders and SandRidge (with respect to incentive distributions) in accordance with the trust agreement;



•

causing to be prepared and distributed a Schedule K-1 for each trust unitholder and causing to be prepared and filed all required tax returns on behalf of the trust; and



•

causing to be prepared and filed reports required to be filed under the Exchange Act, and by the rules of any securities exchange or quotation system on which the trust units are listed or admitted to trading.

        SandRidge provides administrative and other services to the trust in fulfillment of certain of the foregoing duties, pursuant to the administrative services agreement.

        If a trust liability is contingent or uncertain in amount or not yet currently due and payable, the trustee may create a cash reserve to pay for the liability. If the trustee determines that the cash on hand and the cash to be received are insufficient to cover the trust's liability, the trustee may cause the trust to borrow funds required to pay the liabilities. The trust may borrow the funds from any person, including the trustee or its affiliates or, as described below, SandRidge. The terms of such indebtedness, if funds were loaned by the entity serving as trustee or Delaware trustee, would be similar to the terms which such entity would grant to a similarly situated commercial customer with whom it did not have a fiduciary relationship, and such entity shall be entitled to enforce its rights with respect to any such indebtedness as if it were not then serving as trustee or Delaware trustee. If the trust borrows funds, the trust unitholders will not receive distributions until the borrowed funds are repaid (except, in certain circumstances, where the trust borrows funds from SandRidge). For

Table of Contents

information regarding SandRidge's obligation to loan funds to the trust in certain limited circumstances, see "—SandRidge Obligation to Fund Trust Expenses in Certain Circumstances" below.

        Each quarter, the trustee pays trust obligations and expenses and distributes to the trust unitholders the remaining proceeds received from the Royalty Interests and derivatives agreement. The cash held by the trustee as a reserve against future liabilities must be invested in:

•

interest bearing obligations of the United States government;



•

money market funds that invest only in United States government securities;



•

repurchase agreements secured by interest-bearing obligations of the United States government; or



•

bank certificates of deposit.

Alternatively, cash held for distribution at the next distribution date may be held in a non-interest bearing account.

        The trustee withheld $1.6 million from the first distribution to unitholders in 2011 to pay future trust administrative expenses and establish a $1.0 million cash reserve. As of June 30, 2012, the cash reserve was approximately $1.0 million. If the trustee uses such cash reserve (or any portion thereof) to pay or reimburse trust liabilities or expenses, no further distributions will be made to unitholders (except in respect of any previously determined quarterly cash distribution amount) until the cash reserve is replenished. This cash reserve will be part of the trust estate and will bear interest at the same rate as other cash on hand in the trust estate. Upon the dissolution of the trust, the balance of the cash reserve (including accrued interest thereon) will be distributed to trust unitholders on a pro rata basis.

        The trust may not acquire any asset except the Royalty Interests, the other assets described above under "—Assets of the Trust" and cash and temporary cash investments, and it may not engage in any investment activity except investing cash on hand.

        The trust agreement provides that the trustee will not make business decisions affecting the assets of the trust. However, the trustee may:

•

prosecute or defend, and settle, claims of or against the trust or its agents;



•

retain professionals and other third parties to provide services to the trust;



•

charge for its services as trustee;



•

retain funds to pay for future expenses and deposit them with one or more banks or financial institutions (which may include the trustee to the extent permitted by law);



•

lend funds at commercial rates to the trust to pay the trust's expenses; and



•

seek reimbursement from the trust for its out-of-pocket expenses.

        In discharging its duty to trust unitholders, the trustee may act in its discretion and will be liable to the trust unitholders only for willful misconduct, bad faith or gross negligence. The trustee will not be liable for any act or omission of its agents or employees unless the trustee acted with willful misconduct, bad faith or gross negligence in its selection and retention. The trustee will be indemnified individually or as the trustee for any liability or cost that it incurs in the administration of the trust, except in cases of willful misconduct, bad faith or gross negligence. The trustee will have a lien on the assets of the trust as security for this indemnification and its compensation earned as trustee. Trust unitholders will not be liable to the trustee for any indemnification. See "Description of the Trust Units—Liability of Trust Unitholders." The trustee will ensure that all contractual liabilities of the trust are limited to the assets of the trust.

Table of Contents

Merger or Consolidation of Trust

        The trust may merge or consolidate with or into, or convert into, one or more limited partnerships, general partnerships, corporations, business trusts, limited liability companies, or associations or unincorporated businesses if such transaction is agreed to by the trustee and approved by the vote of the holders of a majority of the trust units and a majority of the common units (excluding common units owned by SandRidge and its affiliates) in each case voting in person or by proxy at a meeting of such holders at which a quorum is present and such transaction is permitted under the Delaware Statutory Trust Act and any other applicable law. At any time that SandRidge and its affiliates collectively own less than 10% of the outstanding trust units, however, the standard for approval will be the vote of a majority of the trust units, including units owned by SandRidge voting in person or by proxy at a meeting of such holders at which a quorum is present.

Trustee's Power to Sell Royalty Interests

        The trustee may sell the Royalty Interests under any of the following circumstances:

•

the sale is requested by SandRidge, following the satisfaction of its drilling obligation, in accordance with the provisions of the trust agreement; or



•

the sale is approved by the vote of holders representing a majority of the trust units and a majority of the common units (excluding common units owned by SandRidge and its affiliates) in each case voting in person or by proxy at a meeting of such holders at which a quorum is present; except that at any time that SandRidge and its affiliates collectively own less than 10% of the outstanding trust units, the standard for approval will be the vote of a majority of the trust units, including units owned by SandRidge voting in person or by proxy at a meeting of such holders at which a quorum is present.

        Upon dissolution of the trust after the occurrence of certain events, the trustee must sell the Royalty Interests. No trust unitholder approval is required in this event. See "—Duration of the Trust; Sale of Royalty Interests" below.

        The trustee will distribute the net proceeds from any sale of the Royalty Interests and other assets to the trust unitholders after payment or reasonable provision for payment of the liabilities of the trust.

Permitted Amendments

        The trustee may amend or supplement the trust agreement, the conveyances, the development agreement, the administrative services agreement, the derivatives agreement, the registration rights agreement or the Drilling Support Lien, without the approval of the trust unitholders, to cure ambiguities, to correct or supplement defective or inconsistent provisions, to grant any benefit to all trust unitholders, to add collateral to the Drilling Support Lien, to evidence or implement any changes required by applicable law or to change the name of the trust, provided, however, that any such supplement or amendment does not adversely affect the interests of the trust unitholders. Furthermore, the trustee, acting alone, may amend the administrative services agreement without the approval of trust unitholders if such amendment would not increase the cost or expense of the trust or create an adverse economic impact on the trust unitholders.

        All other permitted amendments to the trust agreement and other agreements listed above may only be made by the vote of a majority of the trust units and a majority of the common units (excluding common units owned by SandRidge and its affiliates) in each case voting in person or by proxy at a meeting of such holders at which a quorum is present; except that at any time that SandRidge and its affiliates collectively own less than 10% of the outstanding trust units, the standard for approval will be the vote of a majority of the trust units, including units owned by SandRidge voting

Table of Contents

in person or by proxy at a meeting of such holders at which a quorum is present. Abstentions and broker non-votes shall not be deemed to be a vote cast.

Liabilities of the Trust; Fees and Expenses

        The trust is a party to the derivatives agreement with SandRidge and could have payment obligations under such agreement. Otherwise, the trust does not conduct an active business and the trustee has little power to incur obligations. As a result, it is expected that the trust will only incur liabilities for routine administrative expenses, such as legal, accounting, tax advisory, engineering, printing and other administrative and out-of-pocket fees and expenses incurred by or at the direction of the trustee or the Delaware trustee, including tax return and Schedule K-1 preparation and mailing costs, independent auditor fees, and registrar and transfer agent fees. The trust is also responsible for paying costs associated with annual and quarterly reports to unitholders. Moreover, the trustee's and the Delaware trustee's compensation and the fee payable to SandRidge pursuant to the administrative services agreement are paid out of the trust's assets.

SandRidge Obligation to Fund Trust Expenses in Certain Circumstances

        SandRidge has agreed that, 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, upon written request of the trustee, loan funds to the trust in such amounts as the trustee certifies is 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. 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 made by SandRidge to the trust shall: (i) be evidenced by a written promissory note executed by the trustee on behalf of the trust, (ii) be on an unsecured basis, (iii) have a maturity date no later than the Termination Date, (iv) have terms (including interest rate) that are no less favorable to SandRidge as those that would be obtained in an arms' length transaction between SandRidge and an unaffiliated third party; and (v) be without recourse to the trustee and payable solely out of the assets of the trust.

Duration of the Trust; Sale of Royalty Interests

        The trust will not dissolve until the Termination Date, which is December 31, 2030, unless:

•

the trust sells all of the Royalty Interests;



•

cash available for distribution is less than $1.0 million for any four consecutive quarters;



•

the holders of a majority of the outstanding trust units and a majority of the outstanding common units (excluding common units owned by SandRidge and its affiliates) in each case voting in person or by proxy at a meeting of such holders at which a quorum is present vote in favor of dissolution; except that at any time that SandRidge and its affiliates collectively own less than 10% of the outstanding trust units, the standard for approval will be a majority of the outstanding trust units, including units owned by SandRidge voting in person or by proxy at a meeting of such holders at which a quorum is present; or



•

the trust is judicially dissolved.

        In the case of any of the foregoing, the trustee would sell all of the trust's assets, either by private sale or public auction, and distribute the net proceeds of the sale to the trust unitholders after payment, or reasonable provision for payment, of all trust liabilities.

Table of Contents

Dispute Resolution

        To the fullest extent permitted by law, any dispute, controversy or claimthe DGCL. The effect of this provision is to eliminate our and our stockholders’ rights, through stockholders’ derivative suits on our behalf, to recover monetary damages against a director for a breach of fiduciary duty as a director.

In addition, with certain exceptions, the Bylaws require that may arise between SandRidgewe indemnify our directors and the trustee relatingofficers to the trust will be submittedfullest extent authorized or permitted by applicable law and that we pay such expenses in advance. We also expect to binding arbitration before a panel of three arbitrators.maintain directors’ and officers’ liability insurance. We believe that these indemnifications provisions and insurance are useful to attract and retain qualified directors and executive officers.

Table of Contents

        Unless otherwise advised by counsel or the IRS, the trustee will treat the income and expenses of the trust for each quarter as belonging to the trust unitholders of record on the quarterly record date that occurs in such quarter. Trust unitholders will recognize income and expenses for tax purposes in the quarter the trust receives or pays those amounts, rather than in the quarter the trust distributes them. Minor variances may occur. For example, the trustee could establish a reserve in one quarter that would not result in a tax deduction until a later quarter. The trustee could also make a payment in one quarter that would be amortized for tax purposes over several quarters. See "U.S. Federal Income Tax Considerations."

Transfer of Trust Units

        Trust unitholders may transfer their trust units in accordance with the trust agreement. The trustee does not require either the transferor or transferee to pay a service charge for any transfer of a trust unit. The trustee may require payment of any tax or other governmental charge imposed for a transfer. The trustee may treat the owner of any trust unit as shown by its records as the owner of the trust unit. The trustee will not be considered to know about any claim or demand on a trust unit by any party except the record owner. A person who acquires a trust unit after any quarterly record date will not be entitled to the distribution relating to that quarterly record date. Delaware law governs all matters affecting the title, ownership or transfer of trust units.

Tax Schedules and Periodic Reports

        The trustee causes to be prepared and filed all required trust federal and state income tax and information returns. The trustee causes to be prepared and distributed to trust unitholders a Schedule K-1 that trust unitholders need to correctly report their share of the income and deductions of the trust. The trustee also causes to be prepared and filed reports required to be filed under the Exchange Act, and by the rules of any securities exchange or quotation system on which the trust units are listed or admitted to trading.

        Each trust unitholder and his representatives may examine, for any proper purpose, during reasonable business hours the records of the trust and the trustee.

Liability of Trust Unitholders

        Under the Delaware Statutory Trust Act, trust unitholders are entitled to the same limitation of personal liability extended toand indemnification provisions in our Certificate of Incorporation and Bylaws may discourage stockholders from bringing a lawsuit against directors for breach of private corporations for profit under the General Corporation Law of the State of Delaware. No assurance can be given, however, that the courts in jurisdictions outside of Delaware will give effect to such limitation.

Voting Rights of Trust Unitholders

        The trustee or trust unitholders owning at least 10% of the outstanding trust unitstheir fiduciary duty. These provisions may call meetings of trust unitholders. The trust would be responsible for all costs associated with calling a meeting of trust unitholders unless such meeting is called by the trust unitholders, in which case the trust unitholders would be responsible for all costs associated with calling such meeting of trust unitholders. Meetings must be held in such location as is designated by the trustee in the notice of such meeting. The trustee must send notice of the time and place of the meeting and the matters to be acted upon to all of the trust unitholders at least 20 days and not more than 60 days before the meeting. Trust unitholders representing a majority of trust units outstanding must be present or represented to have a quorum. Each trust unitholder is entitled to one vote for each trust unit owned. Abstentions and broker non-votes shall not be deemed to be a vote cast.

        Unless otherwise required by the trust agreement, a matter may be approved or disapproved by the vote of a majority of the trust units held by the trust unitholders voting in person or by proxy at a

Table of Contents

meeting where there is a quorum. This is true, even if a majority of the total outstanding trust units did not approve it.

        Until such time as SandRidge and its affiliates own less than 10% of the outstanding trust units, the vote of the holders of a majority of common units (excluding common units owned by SandRidge and its Affiliates) and a majority of trust units voting in person or by proxy at a meeting of such holders at which a quorum is present is required to:

•

dissolve the trust (except in accordance with its terms);



•

amend the trust agreement, the royalty conveyances, the administrative services agreement, the development agreement, the Drilling Support Lien or the derivatives agreement (except with respect to certain matters that do not adversely affect the right of trust unitholders in any material respect);



•

merge or consolidate or convert the trust with or into another entity; or



•

approve the sale of all or any material part of the assets of the trust.

        In addition, until such time as SandRidge and its affiliates own less than 10% of the outstanding trust units, the vote of the holders of a majority of common units (excluding common units owned by SandRidge and its affiliates) voting in person or by proxy at a meeting of such holders at which a quorum is present is required to remove the trustee and to appoint a successor trustee.

        At any time when SandRidge and its affiliates own less than 10% of the outstanding trust units, the vote of the holders of a majority of trust units, including units owned by SandRidge voting in person or by proxy at a meeting of such holders at which a quorum is present will be required to take the actions described above.

        Certain amendments to the trust agreement may be made by the trustee without approval of the trust unitholders. The trustee must consent before all or any part of the trust assets can be sold except in connection with the dissolution of the trust or limited sales directed by SandRidge in conjunction with its sale of Underlying Properties.

Comparison of Trust Units and Common Stock

        Trust unitholders have more limited voting rights than those of stockholders of most public corporations. For example, there is no requirement for annual meetings of trust unitholders or for annual or other periodic re-election of the trustee.

Table of Contents

        Unitholders should also be aware of the following ways in which an investment in trust units is different from an investment in common stock of a corporation.

Registration Rights

        On April 12, 2011, the trust entered into a registration rights agreement for the benefit of SandRidge and certain of its affiliates and transferees, including the selling unitholder, pursuant to which the trust agreed to register the offering of the trust units held by SandRidge and certain of its affiliates and permitted transferees upon request by SandRidge. Specifically, the trust agreed:

•

subject to certain restrictions, to use its reasonable best efforts to file a registration statement, including, if so requested, a shelf registration statement, with the SEC as promptly as practicable following receipt of a notice requesting the filing of a registration statement from holders representing a majority of the then outstanding registrable trust units;

Table of Contents

•

to use its reasonable best efforts to cause the registration statement or shelf registration statement to be declared effective under the Securities Act, as promptly as practicable after the filing thereof; and



•

to continuously maintain the effectiveness of the registration statement under the Securities Act for 90 days (or continuously if a shelf registration statement is requested) after the effectiveness thereof or until the trust units covered by the registration statement have been sold pursuant to such registration statement or until all registrable trust units:



•

have been sold pursuant to Rule 144 under the Securities Act if the transferee thereof does not receive "restricted securities";



•

have been sold in a private transaction in which the transferor's rights under the registration rights agreement are not assigned to the transferee of the trust units; or



•

become eligible for resale pursuant to Rule 144 (or any similar rule then in effect under the Securities Act).

        In connection with the preparation and filing of any registration statement, SandRidge agreed to bear all costs and expenses incidental to any registration statement, excluding certain internal expenses of the trust, which would be borne by the trust, and any underwriting discounts and commissions, which would be borne by the seller of the trust units.

        Under the registration rights agreement, SandRidge and certain of its affiliates and permitted transferees have the right to requireeffect of reducing the trust to file no more than five registration statements in aggregate. The registration statementlikelihood of which this prospectus forms a part counts as onederivative litigation against directors and officers, even though such registration statement.action, if successful, might otherwise benefit us and our stockholders.

Listing of Common Units

        The common units are listed on the New York Stock Exchange under the symbol "SDT."

Transfer Agent and Registrar

The transfer agent and registrar for theour common unitsstock is American Stock Transfer & Trust Company, LLC.

Listing

Table of Contents

U.S. FEDERAL INCOME TAX CONSIDERATIONS

        This sectionOur common stock is a discussion oflisted on the material tax considerations that may be relevant to prospective trust unitholders who are individual citizens or residents of the United States and, unless otherwise noted in the following discussion, is the opinion of Covington & Burling LLP, counsel to SandRidge, insofar as it relates to legal conclusions with respect to matters of U.S. federal income tax law. This section is based upon current provisions of the Internal Revenue Code of 1986, as amended (the "Internal Revenue Code"), existing and proposed Treasury regulations promulgatedNYSE under the Internal Revenue Codesymbol “SD.”

Warrant Agreement

On October 4, 2016 (the "Treasury Regulations") and current administrative rulings and court decisions, all of which are subject to change. Future changes in these authorities may cause the tax consequences to vary substantially from the consequences described below.

        The following discussion does not address all U.S. federal income tax matters affecting the trust or the trust unitholders. Moreover, the discussion focuses on trust unitholders who are individual citizens or residents of the United States and has only limited application to corporations, estates, trusts, nonresident aliens or other unitholders subject to specialized tax treatment, such as tax-exempt institutions, non-U.S. persons, taxpayers subject to the alternative minimum tax, individual retirement accounts (IRAs), employee benefit plans, real estate investment trusts (REITs) or mutual funds. Accordingly, the trust encourages each prospective trust unitholder to consult, and depend on, his own tax advisor in analyzing the federal, state, local and foreign tax consequences particular to him of the ownership or disposition of trust units.

        No ruling has been or will be requested from the Internal Revenue Service (the "IRS") regarding any matter affecting the trust or prospective trust unitholders. Instead, the trust will rely on opinions of counsel. Unlike a ruling, an opinion of counsel represents only that counsel's best legal judgment and does not bind the IRS or the courts. Accordingly, the opinions and statements made herein may not be sustained by a court if contested by the IRS. Any contest of this sort with the IRS may materially and adversely impact the market for the trust units and the prices at which trust units trade. In addition, the costs of any contest with the IRS, principally legal, accounting and related fees, will result in a reduction in cash available for distribution to the trust unitholders, and thus will be borne indirectly by the trust unitholders. Furthermore, the tax treatment of the trust, or of an investment in the trust, may be significantly modified by future legislative or administrative changes or court decisions. Any modifications may or may not be retroactively applied.

        All statements as to matters of law and legal conclusions, but not as to factual matters, contained in this section, unless otherwise noted, are the opinion of Covington & Burling LLP and are based on the accuracy of the representations made by SandRidge and the trust.

        For the reasons described below, Covington & Burling LLP has not rendered an opinion with respect to the following specific U.S. federal income tax issues: (1) the treatment of a trust unitholder whose trust units are loaned to a short seller to cover a short sale of trust units (please read "—Tax Consequences of Trust Unit Ownership—Treatment of Short Sales"); (2) whether the trust's convention for allocating taxable income and losses is permitted by existing Treasury Regulations (please read "—Disposition of Trust Units—Allocations Between Transferors and Transferees"); and (3) whether percentage depletion will be available to a trust unitholder or the extent of the percentage depletion deduction available to any trust unitholder (please read "—Tax Consequences of Trust Unit Ownership—Tax Treatment of the Perpetual Royalties").

        As used herein, the term "trust unitholder" means a beneficial owner of trust units that for U.S. federal income tax purposes is:

•

an individual who is a citizen of the United States or who is resident in the United States for U.S. federal income tax purposes,

Table of Contents

•

a corporation, or an entity treated as a corporation for U.S. federal income tax purposes, created or organized in or under the laws of the United States, a state thereof or the District of Columbia,



•

an estate the income of which is subject to U.S. federal income taxation regardless of its source, or



•

a trust if it is subject to the primary supervision of a U.S. court and the control of one or more United States persons (as defined for U.S. federal income tax purposes) or that has a valid election in effect under applicable U.S. Treasury regulations to be treated as a United States person.

        The term "non-U.S. trust unitholder" means any beneficial owner of a trust unit (other than an entity that is classified for U.S. federal income tax purposes as a partnership or as a "disregarded entity") that is not a trust unitholder.

        If an entity that is classified for U.S. federal income tax purposes as a partnership is a beneficial owner of trust units, the tax treatment of a member of the entity will depend upon the status of the member and the activities of the entity. The trust encourages any entity that is classified for U.S. federal income tax purposes as a partnership and that is a beneficial owner of trust units, and the members of such an entity, to consult their own tax advisors about the U.S. federal income tax considerations of purchasing, owning, and disposing of trust units.

Classification of the Trust as a Partnership

        Although the trust is formed as a statutory trust under Delaware law, the trust's classification for U.S. federal income tax purposes is based on its characteristics rather than its form. Based on such characteristics, it is expected that, as described below, the trust will be treated for federal and applicable state income tax purposes as a partnership and trust unitholders will be treated as partners in that partnership.

        A partnership is not a taxable entity and incurs no U.S. federal income tax liability. Instead, each partner of a partnership is required to take into account his share of items of income, gain, loss, deduction and credit of the partnership in computing his federal income tax liability, regardless of whether cash distributions are made to him by the partnership. Distributions by a partnership to a partner are generally not taxable to the partner unless the amount of cash distributed to him is in excess of the partner's adjusted basis in his partnership interest as of the end of the taxable year in which the distribution is made.

        Section 7704 of the Internal Revenue Code provides that publicly traded partnerships will, as a general rule, be taxed as corporations. However, an exception, referred to in this discussion as the "Qualifying Income Exception," exists with respect to publicly traded partnerships of which 90% or more of the gross income for every taxable year consists of "qualifying income." Qualifying income includes income and gains derived from the exploration, development, production and marketing of oil, including natural gas liquids, and natural gas and interest income (other than from a financial business). Other types of qualifying income include gains from the sale of real property and income from certain hedging transactions. The trust anticipates that substantially all of its gross income will be qualifying income. Based upon the factual representations made by the trust and SandRidge and a review of the applicable legal authorities, Covington & Burling LLP is of the opinion that at least 90% of the trust's gross income will constitute qualifying income.

        No ruling has been or will be sought from the IRS and the IRS has made no determination as to the trust's status for federal income tax purposes or whether the trust's operations generate "qualifying income" under Section 7704 of the Internal Revenue Code. Instead, the trust will rely on the opinion of Covington & Burling LLP on such matters. It is the opinion of Covington & Burling LLP that,

Table of Contents

based upon the Internal Revenue Code, Treasury Regulations, published revenue rulings and court decisions and the representations described below, the trust will be classified as a partnership for federal income tax purposes.

        In rendering its opinion, Covington & Burling LLP has relied on factual representations made by the trust and SandRidge. The representations made by the trust and SandRidge upon which Covington & Burling LLP has relied are:

        (a)   The trust has not, and will not, elect to be treated as a corporation;

        (b)   The trust is, and will be organized and operated in accordance with (i) all applicable trust statutes, including the Delaware Statutory Trust Act, (ii) the trust agreement, and (iii) the description thereof in this prospectus;

        (c)   For each taxable year, more than 90% of the trust's gross income will be income that Covington & Burling LLP has opined or will opine is qualifying income within the meaning of Section 7704(d) of the Internal Revenue Code; and

        (d)   Each hedging transaction that the trust treats as resulting in qualifying income will be appropriately identified as a hedging transaction pursuant to applicable Treasury Regulations, and will be associated with oil, gas or products thereof that are held or will be held by the trust in activities that Covington & Burling LLP has opined or will opine result in qualifying income.

        The trust believes that these representations are true and expects that these representations will continue to be true in the future.

        If the trust fails to meet the Qualifying Income Exception, other than a failure that is determined by the IRS to be inadvertent and that is cured within a reasonable time after discovery (in which case the IRS may also require the trust to make adjustments with respect to the trust's unitholders allocable share of trust income, gain, loss or deduction or pay other amounts), the trust will be treated as if it had transferred all of its assets, subject to liabilities, to a newly formed corporation, on the first day of the year in which the trust fails to meet the Qualifying Income Exception, in return for stock in that corporation, and then distributed that stock to the unitholders in liquidation of their interests in the trust. This deemed contribution and liquidation should be tax-free to the trust unitholders and the trust. Thereafter, the trust would be treated as an association taxable as a corporation for federal income tax purposes.

        If the trust were treated as an association taxable as a corporation in any taxable year, either as a result of a failure to meet the Qualifying Income Exception or otherwise, the trust's items of income, gain, loss and deduction would be reflected only on the trust's tax return rather than being passed through to the trust unitholders, and the trust's net income would be taxed to the trust at corporate rates. In addition, any distribution made to a trust unitholder would be treated as either taxable dividend income, to the extent of the trust's current or accumulated earnings and profits, or, in the absence of earnings and profits, a nontaxable return of capital, to the extent of the trust unitholder's tax basis in his trust units, or taxable capital gain, after the trust unitholder's tax basis in his trust units is reduced to zero. Accordingly, taxation as a corporation would result in a material reduction in a trust unitholder's cash flow and after-tax return and thus would likely result in a substantial reduction of the value of the trust units.

        The discussion below is based on Covington & Burling LLP's opinion that the trust will be classified as a partnership for U.S. federal income tax purposes.

Partner Status

        Trust unitholders will be treated as partners of the trust for U.S. federal income tax purposes. Also, trust unitholders whose trust units are held in street name or by a nominee and who have the

Table of Contents

right to direct the nominee in the exercise of all substantive rights attendant to the ownership of their trust units will be treated as partners of the trust for U.S. federal income tax purposes.

        A beneficial owner of trust units whose trust units have been transferred to a short seller to complete a short sale would appear, as a result, to lose his status as a partner with respect to those trust units for U.S. federal income tax purposes. Please read "—Tax Consequences of Trust Unit Ownership—Treatment of Short Sales." Income, gain, deductions or losses would not appear to be reportable by a trust unitholder who is not a partner for federal income tax purposes, and any cash distributions received by a trust unitholder who is not a partner for federal income tax purposes would therefore appear to be fully taxable as ordinary income. These unitholders are urged to consult their own tax advisors with respect to their tax considerations related to holding trust units. The references to "unitholders" in the discussion that follows are to persons who are treated as partners in the trust for federal income tax purposes.

Tax Classification of the PDP Royalty Interest and the Development Royalty Interest

        For U.S. federal income tax purposes, a mineral interest similar to the Perpetual PDP Royalty and the Perpetual Development Royalty will have the tax characteristics of mineral royalty interests to the extent they are, at the time of their creation, reasonably expected to have an economic life that corresponds substantially to the economic life of the mineral property or properties burdened thereby. Payments out of production that are received in respect of a mineral interest that constitutes a royalty interest for U.S. federal income tax purposes are taxable under current law as ordinary income subject to an allowance for cost or percentage depletion in respect of such income.

        In contrast, a mineral interest similar to the Term PDP Royalty and the Term Development Royalty will have the tax characteristics of production payments governed by Section 636 of the Internal Revenue Code to the extent they may not, at the time of their creation, be reasonably expected to extend in substantial amounts over the entire productive lives of the mineral property or properties they burden. Payments out of production that are received in respect of a mineral interest that constitutes a production payment for U.S. federal income tax purposes are treated under current law as consisting of a receipt of principal and interest on a nonrecourse debt obligation, with the interest component being taxable as ordinary income.

        In the event that a portion of a single royalty interest terminates by its terms prior to the point in time that the economically productive life of the burdened mineral property is substantially exhausted and the remaining portion continues to burden the property until its economically productive life is substantially exhausted, the federal income tax characteristics of the royalty interest are determined as if it comprised two separate interests, with the terminating portion being treated as a production payment and the continuing portion being treated as a royalty interest.

        Based on the reserve report and representations made by SandRidge regarding the expected economic life of the Underlying Properties and the expected duration of the Term Royalties and the Perpetual Royalties, the Term PDP Royalty will and the Term Development Royalty should be treated as "production payments" under Section 636 of the Internal Revenue Code, and thus as nonrecourse debt instruments of SandRidge for U.S. federal income tax purposes. The Perpetual PDP Royalty will and the Perpetual Development Royalty should be treated as continuing, nonoperating economic interests in the nature of royalties payable out of production from the mineral interests they burden.

        The difference in certainty between the treatment of the Term PDP Royalty and the Perpetual PDP Royalty, on the one hand, and the Term Development Royalty and the Perpetual Development Royalty, on the other hand, stems from the fact that while the Term PDP Royalty and Perpetual PDP Royalty are interests in the Initial Wells (developed wells that were producing or drilled and awaiting completion as of December 31, 2010), the Term Development Royalty and Perpetual Development Royalty are interests in the Trust Development Wells (undeveloped wells that, as of December 31, 2010,

Table of Contents

were to be drilled in the future). The applicable laws are well developed, and directly applicable precedents exist, with regard to the tax treatment of royalty interests in specified developed wells that have been drilled. Although such laws and precedents are applicable in analyzing the tax treatment of royalty interests in proven reserves and undeveloped wells related thereto that will be drilled in the future, the law is less well developed in this area. As a result, the tax treatment of the Term Development Royalty and the Perpetual Development Royalty are not entirely free from doubt. Therefore, the difference in certainty between the treatment of the PDP Royalties and the Development Royalties set forth in the preceding paragraph and elsewhere in this prospectus reflects the difference in certainty between developed and undeveloped wells.

        Consistent with the foregoing, SandRidge and the trust intend to treat the Perpetual Royalties as mineral royalty interests for U.S. federal income tax purposes. In addition, SandRidge and the trust intend to treat the Term Royalties as debt instruments for U.S. federal income tax purposes subject to the Treasury Regulations applicable to contingent payment debt instruments (the "CPDI regulations"“Emergence Date”), andwe entered into a warrant agreement (the “Warrant Agreement”) with American Stock Transfer & Trust Company, LLC, as warrant agent. On the trust has agreed to be bound by SandRidge's application of the CPDI regulations, including SandRidge's determination of the rate at which interest will be deemed to accrue on such interests. The remainder of this discussion assumes that the Term Royalties will be treated in accordance with that agreement and SandRidge's determinations and that the Perpetual Royalties will be treated as mineral royalty interests. No assurance can be given that the IRS will not assert that such interests should be treated differently. Such different treatment could affect the amount, timing and character of income, gain or loss in respect of an investment in trust units and could require a trust unitholder to accrue interest income at a rate different than the "comparable yield" described below. Please read "—Tax Consequences of Trust Unit Ownership—Tax Treatment of the Term Royalties," and "—Tax Consequences of Trust Unit Ownership—Tax Treatment of the Perpetual Royalties."

Tax Consequences of Trust Unit Ownership

        Flow-Through of Taxable Income.    As a partnership for U.S. federal income tax purposes, the trust is not a taxable entity required to pay any federal income tax. Instead, each trust unitholder will be required to report on his income tax return his allocable share of the trust's income, gains, losses, deductions and credits without regard to whether the trust makes cash distributions to him. Consequently, the trust may allocate taxable income to a trust unitholder even if he has not received a cash distribution.

        Accounting Method and Taxable Year.    The trust uses the year ending December 31 as its taxable year and the accrual method of accounting for U.S. federal income tax purposes. Each trust unitholder will be required to include in income his share of the trust's income, gain, loss, deduction and credit for the trust's taxable year ending within or with his taxable year. In addition, a trust unitholder who has a taxable year ending on a date other than December 31 and who disposes of all of his trust units following the close of the trust's taxable year but before the close of his taxable year must include his share of the trust's income, gain, loss, deduction and credit in his taxable income for his taxable year, with the result that he will be required to include in income for his taxable year his share of more than 12 months of the trust's income, gain, loss, deduction and credit. Please read "—Disposition of Trust Units—Allocations Between Transferors and Transferees."

        A trust unitholder's initial tax basis for his trust units will be the amount he paid for the trust units. That basis will be increased by his share of the trust's income and gain and decreased, but not below zero, by distributions from the trust, by the trust unitholder's share of the trust's losses, if any, by depletion deductions taken by him to the extent such deductions do not exceed his proportionate allocated share of the adjusted tax basis of the Perpetual Royalties, and by his share of the trust's expenditures that are not deductible in computing taxable income and are not required to be capitalized. Please read "—Disposition of Trust Units—Recognition of Gain or Loss."

Table of Contents

        Allocation of Income, Gain, Loss, Deduction and Credit.    In general, if the trust has a net profit, the trust's items of income, gain, loss, deduction and credit will be allocated among the trust unitholders in accordance with their percentage interests in the trust. At any time that distributions are made to the common units in excess of distributions to the subordinated trust units, or SandRidge receives incentive distributions, gross income will be allocated to the recipients to the extent of these distributions. If the trust has a net loss, that loss will be allocated first to the subordinated trust units to the extent of their positive capital accounts and thereafter to the trust unitholders in accordance with their percentage interests in the trust.

        Specified items of the trust's income, gain, loss, deduction and credit will be allocated under Section 704(c) of the Internal Revenue Code to account for any difference between the tax basis and fair market value of any property treated as having been contributed to the trust by SandRidge or certain of its affiliates that exists at the time of such contribution, together, referred to in this discussion as the "Contributed Property." These "Section 704(c) Allocations" are required to eliminate the difference between a partner's "book" capital account, credited with the fair market value of Contributed Property, and the "tax" capital account, credited with the tax basis of Contributed Property, referred to in this discussion as the "Book-Tax Disparity." The effect of these Section 704(c) Allocations to a unitholder purchasing trust units from the trust in this offering will be essentially the same as if the tax bases of the trust's assets were equal to their fair market value at the time of this offering. Finally, although the trust does not expect that its operations will result in the creation of negative capital accounts, if negative capital accounts nevertheless result, items of the trust's income and gain will be allocated in an amount and manner sufficient to eliminate the negative balance as quickly as possible.

        An allocation of items of the trust's income, gain, loss, deduction or credit, other than an allocation required by Section 704(c) of the Internal Revenue Code to eliminate the Book-Tax Disparity, will generally be given effect for U.S. federal income tax purposes in determining a unitholder's share of an item of income, gain, loss, deduction or credit only if the allocation has substantial economic effect. In any other case, a unitholder's share of an item will be determined on the basis of his interest in the trust, which will be determined by taking into account all the facts and circumstances, including:

•

his relative contributions to the trust;



•

the interests of all the unitholders in profits and losses;



•

the interest of all the unitholders in cash flow; and



•

the rights of all the unitholders to distributions of capital upon liquidation.

        Covington & Burling LLP is of the opinion that, with the exception of the issues described in "Disposition of Trust Units—Allocations Between Transferors and Transferees," allocations under the trust agreement will be given effect for U.S. federal income tax purposes in determining a unitholder's share of an item of income, gain, loss, deduction or credit.

        Treatment of Trust Distributions.    Distributions by the trust to a trust unitholder generally will not be taxable to the trust unitholder for U.S. federal income tax purposes, except to the extent the amount of any such cash distribution exceeds his tax basis in his trust units immediately before the distribution. The trust's cash distributions in excess of a unitholder's tax basis (if any) generally will be considered to be gain from the sale or exchange of the trust units, taxable in accordance with the rules described under "—Disposition of Trust Units" below.

        Tax Treatment of the Term Royalties.    Under the CPDI regulations, the trust generally will be required to accrue income on the Term Royalties which are treated as production payments, and

Table of Contents

therefore as nonrecourse debt obligations of SandRidge for U.S. federal income tax purposes, in the amounts described below.

        The CPDI regulations provide that the trust must accrue an amount of ordinary interest income for U.S. federal income tax purposes, for each accrual period prior to and including the maturity date of the debt instrument that equals:

•

the product of (i) the adjusted issue price (as defined below) of the debt instrument as of the beginning of the accrual period; and (ii) the comparable yield to maturity (as defined below) of such debt instrument, adjusted for the length of the accrual period;



•

divided by the number of days in the accrual period; and



•

multiplied by the number of days during the accrual period that the trust held the debt instrument.

        The "issue price" of the debt instrument represented by each production payment held by the trust is the portion of the first price at which a substantial amount of the trust units were sold to the public in the initial public offering of units, excluding sales to bond houses, brokers or similar persons or organizations acting in the capacity of underwriters, placement agents or wholesalers, that is allocable to the production payment based on the relative fair market value of the production payment to the other assets of the trust. The "adjusted issue price" of such a debt instrument is its issue price increased by any interest income previously accrued, determined without regard to any adjustments to interest accruals described below, and decreased by the projected amount of any payments scheduled to be made with respect to the debt instrument at an earlier time (without regard to the actual amount paid). The term "comparable yield" means the annual yield SandRidge would be expected to pay, as of the initial issue date, on a fixed rate debt security with no contingent payments but with terms and conditions otherwise comparable to those of the debt instrument represented by the production payment.

        SandRidge determined the comparable yield and provided this information to the trust. In addition, the CPDI regulations require that SandRidge provide to the trust, solely for determining the amount of interest accruals for U.S. federal income tax purposes, a schedule of the projected amounts of payments, which are referred to as projected payments, on the Term Royalties treated as debt instruments held by the trust. These payments set forth on the schedule must produce a total return on such debt instruments equal to their comparable yield. Amounts treated as interest under the CPDI regulations are treated as original issue discount for all purposes of the Internal Revenue Code.

        As required by the CPDI regulations, for U.S. federal income tax purposes, the trust must use the comparable yield and the schedule of projected payments as described above in determining the trust's interest accruals, and the adjustments thereto described below, in respect of the debt instruments held by the trust.

        SandRidge's determinations of the comparable yield and the projected payment schedule are not binding on the IRS and it could challenge such determinations. If it did so, and if any such challenge were successful, then the amount and timing of interest income accruals of the trust would be different from those reported by the trust or included on previously filed tax returns by the trust unitholders.

        The comparable yield and the schedule of projected payments are not determined for any purpose other than for the determination for U.S. federal income tax purposes of the trust's interest accruals and adjustments thereof in respect of the debt instruments held by the trust and do not constitute a projection or representation regarding the actual amounts payable to the trust.

        For U.S. federal income tax purposes, the trust is required under the CPDI regulations to use the comparable yield and the projected payment schedule established by SandRidge in determining interest accruals and adjustments in respect of the production payments, unless the trust timely discloses and

Table of Contents

justifies the use of a different comparable yield and projected payment schedule to the IRS. PursuantEmergence Date, pursuant to the terms of the conveyance, SandRidgeCompany and its direct subsidiaries Joint Plan of Reorganization dated September 9, 2016 (the “Plan”), we issued or reserved for issuance as consideration payable to certain of the trust have agreed (inCompany’s creditors under the absencePlan 4,913,251 Series A Warrants and 2,068,690 Series B Warrants to certain Holders of an administrative determination or judicial rulingGeneral Unsecured Claims (as defined in the Plan) (the Series A Warrants and Series B Warrants collectively referred to as the “Warrants”).

The Warrants are exercisable from the date of the Warrant Agreement until 5:00 p.m., New York City time, on October 4, 2022. The Warrants are initially exercisable for one share of common stock per Warrant (such rate, as adjusted pursuant to the contrary)Warrant Agreement, being the “Warrant Share Number”) at an initial exercise price of $41.34 for the Series A Warrants and $42.03 for the Series B Warrants (each, an “Exercise Price”).

No Rights as Stockholders

Pursuant to be boundthe Warrant Agreement, warrant holders are not entitled, by SandRidge's determinationvirtue of the comparable yield and projected payment schedule.

        If, during any taxable year, the trust receives actual paymentsholding Warrants, to vote, to consent, to receive dividends, to receive notice as stockholders with respect to a debt instrument held byany meeting of stockholders for the trust that in the aggregate exceed the total amountelection of projected payments for that taxable year, the trust will incur a "net positive adjustment" under the CPDI regulations equalour directors or any other matter, or to the amount of such excess. The trust will treat a "net positive adjustment"exercise any rights whatsoever as additional interest income for such taxable year.

        If the trust receives in a taxable year actual payments with respect to a debt instrument held by the trust that in the aggregate are less than the amount of projected payments for that taxable year, the trust will incur a "net negative adjustment" under the CPDI regulations equal to the amount of such deficit. This adjustment will (a) reduce the trust's interest income on the debt instrument held by the trust for that taxable year,our stockholders unless, until and (b) to the extent of any excess after the application of (a) give rise to an ordinary loss to the extent of the trust's interest income on such debt instrument during prior taxable years, reducedonly to the extent such interest was offset by prior net negative adjustments. Any negative adjustment in excessholders become holders of record of shares of common stock issuable upon exercise of the amount describedWarrants.

Adjustments

The Warrant Share Number and each applicable Exercise Price are subject to customary anti-dilution adjustments. No adjustments to the applicable Exercise Price or Warrant Share Number are required unless the cumulative adjustments required would result in (a) and (b) willan increase or decrease of at least 1.0% in the applicable Exercise Price. Additionally, no adjustment need be carried forward, asmade for a negative adjustment to offset future interest incomechange in respect of that debt instrument held by the trust. If eitherpar value of the Term Royalties is not treatedcommon stock.

Deemed Liquidation Event

All Warrants outstanding as of the close of business on the trading day immediately preceding the day on which a production payment (and not otherwise as a debt instrument) for U.S. federal income tax purposes, the trust intends to take the position that its basisDeemed Liquidation Event (as defined in the Term Royalty is recoupedWarrant Agreement) occurs (the “Automatic Exercise Time”) shall be deemed exercised upon the occurrence of such Deemed Liquidation Event and settled as set forth in proportion to the production from the Term Royalty.

        A holder that acquires a trust unit at a price such that the price allocable to the production payment is different than the "adjusted issue price"Warrant Agreement. Each person in whose name any shares of the debt instrument represented by the production payment will,common stock are issued as a result of an automatic exercise triggered by a Deemed Liquidation Event shall for all purposes be deemed to have become the Section 754 election described below, obtainholder of record of such shares as of the Automatic Exercise Time.

Table of Contents

income of the trust unitholder from the property for each taxable year, computed without the depletion allowance. A trust unitholder that qualifies as an independent producer may deduct percentage depletion only to the extent the trust unitholder's average daily production of domestic oil, or the natural gas equivalent, does not exceed 1,000 barrels. This depletable amount may be allocated between oil, including natural gas liquids, and natural gas production, with 6,000 cubic feet of domestic oil, including natural gas liquids, and natural gas production regarded as equivalent to one barrel of crude oil. The 1,000-barrel limitation must be allocated among the independent producer and controlled or related persons and family members in proportion to the respective production by such persons during the period in question.

        In addition to the foregoing limitations, the percentage depletion deduction otherwise available is limited to 65% of a trust unitholder's total taxable income from all sources for the year, computed without the depletion allowance, the deduction for domestic production activities, net operating loss carrybacks, or capital loss carrybacks. Any percentage depletion deduction disallowed because of the 65% limitation may be deducted in the following taxable year if the percentage depletion deduction for such year plus the deduction carryover does not exceed 65% of the trust unitholder's total taxable income for that year. The carryover period resulting from the 65% net income limitation is unlimited.

        In addition to the limitations on percentage depletion discussed above, President Obama's budget proposals for recent fiscal years proposed to eliminate certain tax preferences applicable to taxpayers engaged in the exploration or production of natural resources. Specifically, these budgets proposed to repeal the deduction for percentage depletion with respect to wells, in which case only cost depletion would be available. It is uncertain whether this or any other legislative proposals will ever be enacted and, if so, when any such proposal would become effective.

        Trust unitholders that do not qualify under the independent producer exemption are generally restricted to depletion deductions based on cost depletion. Cost depletion deductions are calculated by (i) dividing the trust unitholder's allocated share of the adjusted tax basis in the underlying mineral property by the number of mineral units (barrels of oil and thousand cubic feet of natural gas) remaining as of the beginning of the taxable year and (ii) multiplying the result by the number of mineral units sold within the taxable year. The total amount of deductions based on cost depletion cannot exceed the trust unitholder's share of the total adjusted tax basis in the property.

        The foregoing discussion of depletion deductions does not purport to be a complete analysis of the complex legislation and Treasury Regulations relating to the availability and calculation of depletion deductions by the trust unitholders. Further, because depletion is required to be computed separately by each trust unitholder and not by the trust, no assurance can be given, and counsel is unable to express any opinion, with respect to the availability or extent of percentage depletion deductions to the trust unitholders for any taxable year. The trust encourages each prospective trust unitholder to consult his tax advisor to determine whether percentage depletion would be available to him.

        Tax Treatment Upon Sale of the Perpetual Royalties at Termination Date.    The sale of the Perpetual Royalties by the trust at or shortly after the Termination Date will generally give rise to long-term capital gain or loss to the trust unitholders for U.S. federal income tax purposes, except that any gain will be taxed at ordinary income rates to the extent of depletion deductions that reduced the trust unitholder's adjusted basis in the Perpetual Royalties. Each trust unitholder will be responsible for calculating his gain or loss based on the difference between his pro-rata share ofWarrant, the amount realized on the sale by the trust and his adjusted basis in the Perpetual Royalties,kind of securities and ifproperty that a gain is realized, the portion thereof taxable as ordinary income by reasonholder of depletion deductions previously claimed by such trust unitholder. However, the trust intendscommon stock would have been entitled to furnish each of the trust unitholders with information relating to this calculation for U.S. federal income tax purposes in connection with the final partnership tax return for the trust.

Table of Contents

        Limitations on Deductibility of Losses.    It is not anticipated that the trust will generate losses. Nevertheless, should losses result, trust unitholders must consult their own tax advisors as to the applicability to them of loss limitation rules that could operate to limit the deductibility to a trust unitholder of his share of the trust's losses such as the basis limitation, the "at risk" rules and the passive loss rules. Special passive loss limitation rules apply with respect to publicly-traded partnerships.

        Limitations on Interest Deductions.    The deductibility of a non-corporate taxpayer's "investment interest expense" is generally limited to the amount of that taxpayer's "net investment income." Investment interest expense includes:

•

interest on indebtedness properly allocable to property held for investment;



•

the trust's interest expense attributed to portfolio income; and



•

the portion of interest expense incurred to purchase or carry an interest in a passive activity to the extent attributable to portfolio income.

        The computation of a trust unitholder's investment interest expense will take into account interest on any margin account borrowing or other loan incurred to purchase or carry a trust unit. Net investment income includes gross income from property held for investment and amounts treated as portfolio income under the passive loss rules, less deductible expenses, other than interest, directly connected with the production of investment income, but generally does not include gains attributable to the disposition of property held for investment or qualified dividend income. The IRS has indicated that the net passive income earned by a publicly traded partnership will be treated as investment income to its unitholders for purposes of the investment interest deduction limitation. In addition, the trust unitholder's share of the trust's portfolio income will be treated as investment income.

        Entity-Level Withholdings.    If the trust is required or elects under applicable law to pay any federal, state, local or foreign income tax on behalf of any trust unitholder or any former trust unitholder, the trust is authorized to pay those taxes from its funds. That payment, if made, will be treated as a distribution of cash to the trust unitholder on whose behalf the payment was made. If the payment is made on behalf of a person whose identity cannot be determined, the trust is authorized to treat the payment as a distribution to all current trust unitholders. The trust is authorized to amend its trust agreement in the manner necessary to maintain uniformity of intrinsic tax characteristics of trust units. Payments by the trust as described above could give rise to an overpayment of tax on behalf of an individual trust unitholder in which event the trust unitholder would be required to file a claim in order to obtain a credit or refund.

        Treatment of Short Sales.    A trust unitholder whose trust units are loaned to a "short seller" to cover a short sale of trust units may be considered as having disposed of those units. If so, he would no longer be treated for tax purposes as a partner with respect to those trust units during the period of the loan and may recognize gain or loss from the disposition. As a result, during this period:

•

any of the trust's income, gain, loss, deduction or credit with respect to those trust units would not be reportable by the trust unitholder;



•

any cash distributions received by the trust unitholder as to those trust units would be fully taxable; and



•

all of these distributions would appear to be ordinary income.

        Covington & Burling LLP has not rendered an opinion regarding the tax treatment of a trust unitholder whose trust units are loaned to a short seller to cover a short sale of trust units; therefore, trust unitholders desiring to assure their status as partners and avoid the risk of gain recognition from a loan to a short seller are urged to modify any applicable brokerage account agreements to prohibit their brokers from borrowing and loaning their trust units. The IRS has previously announced that it is

Table of Contents

studying issues relating to the tax treatment of short sales of partnership interests. Please also read "—Disposition of Trust Units—Recognition of Gain or Loss."

        Alternative Minimum Tax.    Each trust unitholder will be required to take into account his distributive share of any items of the trust's income, gain, loss, deduction or credit for purposes of the alternative minimum tax. The current minimum tax rate for non-corporate taxpayers is 26% on the first $175,000 of alternative minimum taxable income in excess of the exemption amount and 28% on any additional alternative minimum taxable income. Prospective trust unitholders are urged to consult with their tax advisors as to the impact of an investment in trust units on their liability for the alternative minimum tax.

        Tax Rates.    Under current law, the highest marginal U.S. federal income tax rate applicable to ordinary income of individuals is 35% and the highest marginal U.S. federal income tax rate applicable to long-term capital gains (generally, capital gains on certain assets held for more than 12 months) of individuals is 15%. However, absent new legislation extending the current rates, beginning January 1, 2013, the highest marginal U.S. federal income tax rate applicable to ordinary income and long-term capital gains of individuals will increase to 39.6% and 20%, respectively. Moreover, these rates are subject to change by new legislation at any time.

        The Health Care and Education Reconciliation Act of 2010 will impose a 3.8% Medicare tax on certain investment income earned by individuals, estates and trusts for taxable years beginning after December 31, 2012. For these purposes, investment income generally includes a trust unitholder's allocable share of the trust's income and gain realized by a trust unitholder from a sale of trust units. In the case of an individual, the tax will be imposed on the lesser of (i) the trust unitholder's net income from all investments, and (ii) the amount by which the trust unitholder's adjusted gross income exceeds $250,000 (if the trust unitholder is married and filing jointly or a surviving spouse), $125,000 (if the trust unitholder is married and filing separately) or $200,000 (if the trust unitholder is not married). In the case of an estate or trust, the tax will be imposed on the lesser of (1) the undistributed net investment income of the estate or trust, or (2) the excess of the adjusted gross income of the estate or trust over the dollar amount at which the highest income tax bracket applicable to an estate or trust begins.

        Section 754 Election.    The trust has made the election permitted by Section 754 of the Internal Revenue Code. That election is irrevocable without the consent of the IRS. The election will generally permit the trust to adjust a subsequent trust unit purchaser's tax basis in the trust's assets ("inside basis") under Section 743(b) of the Internal Revenue Code to reflect his purchase price of trust units acquired from another trust unitholder. The Section 743(b) adjustment belongs to the purchaser and not to other trust unitholders. For purposes of this discussion, a trust unitholder's inside basis in the trust's assets will be considered to have two components: (1) his share of tax basis in the trust's assets ("common basis") and (2) his Section 743(b) adjustment to that basis.

        A Section 754 election is advantageous if the transferee's tax basis in his units is higher than the units' share of the aggregate tax basis of the trust's assets immediately prior to the transfer. In such a case,receive as a result of the election, the transferee would have a higher tax basis in his share of the trust's assets for purposes of calculating, among other items, cost depletion deductions on the Perpetual Royalties, and his share of any gain on a sale of the trust's assets would be less. Conversely, a Section 754 election is disadvantageous if the transferee's tax basis in his units is lower than those trust units' share of the aggregate tax basis of the trust's assets immediately prior to the transfer. Thus, the fair market value of the trust units may be affected either favorably or unfavorably by the election. A basis adjustment is required regardless of whether a Section 754 election is made in the case of a transfer of an interest in the trustsuch Fundamental Change if it hasheld a substantial built-in loss immediately after the transfer. Generally a built-in loss or a basis reduction is substantial if it exceeds $250,000.

Tablenumber of Contents

        The calculations involved in the Section 754 election are complex and will be made on the basisshares of assumptions as to the value of the trust's assets and other matters. For example, the allocation of the Section 743(b) adjustment among the trust's assets must be made in accordance with the Internal Revenue Code. The trust cannot assure unitholders that the determinations it makes will not be successfully challenged by the IRS and that the deductions resulting from them will not be reduced or disallowed altogether. Should the IRS require a different basis adjustment to be made, and should, in the trust's opinion, the expense of compliance exceed the benefit of the election, the trust may seek permission from the IRS to revoke its Section 754 election. If permission is granted, a subsequent purchaser of trust units may be allocated more income than he would have been allocated had the election not been revoked.

        Initial Tax Basis and Amortization.    The initial tax basis of the portion of the PDP Royalty Interest treated as a royalty interest in minerals (the Perpetual PDP Royalty) and the portion treated as a production payment (the Term PDP Royalty), and the initial basis of the portion of the Development Royalty Interest treated as a royalty interest in minerals (the Perpetual Development Royalty) and the portion treated as a production payment (the Term Development Royalty) will be effectivelycommon stock equal on a per-unit basis to the portion of the unit price allocated to each based on each such portion's relative fair market value.

        Valuation and Tax Basis of the Trust's Properties.    The U.S. federal income tax consequences of the ownership and disposition of trust units will depend in part on the trust's estimates of the relative fair market values, and the initial tax bases, of the trust's assets. Although the trust may from time to time consult with professional appraisers regarding valuation matters, the trust will make many of the relative fair market value estimates itself. These estimates and determinations of basis are subject to challenge and will not be binding on the IRS or the courts. If the estimates of fair market value or basis are later found to be incorrect, the character and amount of items of income, gain, loss or deductions previously reported by trust unitholders might change, and trust unitholders might be required to adjust their tax liability for prior years and incur interest and penalties with respect to those adjustments.

Disposition of Trust Units

        Recognition of Gain or Loss.    Gain or loss will be recognized on a sale of trust units equal to the difference between the amount realized and the trust unitholder's tax basis for the trust units sold. A trust unitholder's amount realized will be measured by the sum of the cash or the fair market value of other property received. The amount realized should be reduced by the unused net negative adjustments attributable to the trust units disposed of as described above under "—Tax Consequences of Trust Unit Ownership—Tax Treatment of the Term Royalties." A trust unitholder's adjusted tax basis in his trust units will be equal to the trust unitholder's original purchase price for the trust units, increased by income and decreased by losses or deductions previously allocated to the trust unitholder and by distributions to the trust unitholder and depletion deductions claimed by the trust unitholder.

        Prior distributions from the trust in excess of cumulative net taxable income for a trust unit that decreased a unitholder's tax basis in that trust unit will, in effect, become taxable income if the trust unit is sold at a price greater than the trust unitholder's tax basis in that trust unit, even if the price received is less than his original cost.

        Except as noted below, gain or loss recognized by a trust unitholder, other than a "dealer" in trust units, on the sale or exchange of a trust unit will generally be taxable as capital gain or loss. Capital gain recognized by an individual on the sale of trust units held for more than 12 months will generally be taxed at a maximum U.S. federal income tax rate of 15% through December 31, 2012 and 20% thereafter (absent new legislation extending or adjusting the current rate). However, a portion, which will likely be substantial, of this gain or loss will be separately computed and taxed as ordinary income

Table of Contents

or loss under Section 751 of the Internal Revenue Code to the extent attributable to assets giving rise to "unrealized receivables" the trust owns. The term "unrealized receivables" includes potential recapture items, including depletion recapture. Ordinary income attributable to unrealized receivables such as depletion recapture may exceed net taxable gain realized upon the sale of a trust unit and may be recognized even if there is a net taxable loss realized on the sale of a trust unit. Thus, a trust unitholder may recognize both ordinary income and a capital loss upon a sale of trust units. Net capital losses may offset capital gains and no more than $3,000 of ordinary income, in the case of individuals, and may only be used to offset capital gains in the case of corporations.

        The IRS has ruled that a partner who acquires interests in a partnership in separate transactions must combine those interests and maintain a single adjusted tax basis for all those interests. Upon a sale or other disposition of less than all of those interests, a portion of that tax basis must be allocated to the interests sold using an "equitable apportionment" method, which generally means that the tax basis allocated to the interest sold equals an amount that bears the same relation to the partner's tax basis in his entire interest in the partnership as the value of the interest sold bears to the value of the partner's entire interest in the partnership. Treasury Regulations under Section 1223 of the Internal Revenue Code allow a selling unitholder who can identify trust units transferred with an ascertainable holding period to elect to use the actual holding period of the trust units transferred. Thus, according to the ruling discussed above, a trust unitholder will be unable to select high or low basis trust units to sell as would be the case with corporate stock, but, according to the Treasury Regulations, he may designate specific trust units sold for purposes of determining the holding period of trust units transferred. A trust unitholder electing to use the actual holding period of trust units transferred must consistently use that identification method for all subsequent sales or exchanges of trust units. A trust unitholder considering the purchase of additional trust units or a sale of trust units purchased in separate transactions is urged to consult his tax advisor as to the possible consequences of this ruling and application of the Treasury Regulations.

        Specific provisions of the Internal Revenue Code affect the taxation of some financial products and securities, including partnership interests, by treating a taxpayer as having sold an "appreciated" partnership interest, one in which gain would be recognized if it were sold, assigned or terminated at its fair market value, if the taxpayer or related persons enter(s) into:

•

a short sale;



•

an offsetting notional principal contract; or



•

a futures or forward contract with respect to the partnership interest or substantially identical property.

        Moreover, if a taxpayer has previously entered into a short sale, an offsetting notional principal contract or a futures or forward contract with respect to the partnership interest, the taxpayer will be treated as having sold that position if the taxpayer or a related person then acquires the partnership interest or substantially identical property. The Secretary of the Treasury is also authorized to issue regulations that treat a taxpayer that enters into transactions or positions that have substantially the same effect as the preceding transactions as having constructively sold the financial position.

        Allocations Between Transferors and Transferees.    In general, the trust's taxable income and losses will be determined and allocated on a quarterly basis and such taxable income or loss for a quarter will be apportioned among the trust unitholders in proportion to the number of trust unitsshares of record owned by eachcommon stock that such warrant holder would have received if such Warrant had been exercised immediately prior to such Fundamental Change.

Net Share Settlement

The Warrants generally only permit a holder of themWarrants to exercise the Warrants for net share or “cashless” settlement, except if the common stock is not listed on a national securities exchange as of the openingapplicable exercise date, a holder of Warrants may elect physical settlement instead and pay cash to purchase the shares underlying the Warrant at the then-applicable Exercise Price. If net share settlement applies, we will deliver, without any cash payment therefor, a number of shares of common stock equal to (i)(a) the number of Warrants being exercised, multiplied by (b) the Warrant Share Number (as of the exercise date), multiplied by (ii)(a) the Fair Market Value (as defined in the Warrant Agreement) of one share of common stock as of the exercise date, minus (b) the applicable exchange on whichExercise Price as of the trust units are then traded onexercise date, divided by (iii) the quarterly record date occurringFair Market Value of one share of common stock as of the exercise date.

The description of the Warrant Agreement is qualified in such quarter,its entirety by reference to the full text of the Warrant Agreement, which is referredfiled as Exhibit 4.2 to in this prospectus as the "Allocation Date."

Table of Contents

        Although simplifying conventions are contemplated by the Internal Revenue Code, the use of this method may not be permitted under existing Treasury Regulations. Accordingly, Covington & Burling LLP is unable to opine on the validity of this method of allocating income and deductions between transferor and transferee trust unitholders. If this method is not allowed under the Treasury Regulations, or only applies to transfers of less than all of the trust unitholder's interest, the trust's taxable income or losses might be reallocated among the trust unitholders. The trust is authorized to revise its method of allocation between transferor and transferee trust unitholders, as well as trust unitholders whose interests vary during a taxable year, to conform to a method permitted under future Treasury Regulations.

        Notification Requirements.    A trust unitholder who sells any of his trust units is generally required to notify the trust in writing of that sale within 30 days after the sale (or, if earlier, January 15 of the year following the sale). A purchaser of trust units who purchases trust units from another trust unitholder is also generally required to notify the trust in writing of that purchase within 30 days after the purchase. Upon receiving such notifications, the trust is required to notify the IRS of that transaction and to furnish specified information to the transferor and transferee. Failure to notify the trust of a purchase may, in some cases, lead to the imposition of penalties. However, these reporting requirements do not apply to a sale by an individual who is a citizen of the United States and who affects the sale or exchange through a broker who will satisfy such requirements.

        Technical Termination.    The trust will be considered to have been terminated for tax purposes if there are sales or exchanges which, in the aggregate, constitute 50% or more of the total interests in the trust's capital and profits within a twelve-month period. For purposes of measuring whether the 50% threshold is reached, multiple sales of the same interest are counted only once. A technical termination results in the closing of the trust's taxable year for all trust unitholders. In the case of a trust unitholder reporting on a taxable year other than a calendar year, the closing of the trust's taxable year may result in more than 12 months of the trust's taxable income or loss being includable in his taxable income for the year of termination. A technical termination occurring on a date other than December 31 will result in the trust filing two tax returns (and trust unitholders may receive two Schedule K-1's) for one fiscal year and the cost of the preparation of these returns will be borne by all trust unitholders. The IRS has announced, however, a relief procedure whereby the IRS may permit a publicly traded partnership that has technically terminated to provide only a single Schedule K-1 to unitholders for the short taxable years that result from the technical termination. The trust would be required to make new tax elections after a termination, including a new election under Section 754 of the Internal Revenue Code. A termination could also result in penalties if the trust was unable to determine that the termination had occurred. Moreover, a termination might either accelerate the application of, or subject the trust to, any tax legislation enacted before the termination.

Tax-Exempt Organizations and Certain Other Investors

        Ownership of trust units by employee benefit plans, other tax-exempt organizations, non-resident aliens, non-U.S. corporations and other non-U.S. persons raises issues unique to those investors and, as described below, may have substantially adverse tax consequences to them. If a potential investor is a tax-exempt entity or a non-U.S. person, then it should consult a tax advisor before investing in the trust units.

Table of Contents

        Tax-Exempt Organizations.    Employee benefit plans and most other organizations exempt from U.S. federal income tax including IRAs and other retirement plans are subject to U.S. federal income tax on unrelated business taxable income. Because all of the income of the trust is expected to be royalty income, interest income, hedging income and gain from the sale of real property, none of which is unrelated business taxable income, any such organization exempt from U.S. federal income tax is not expected to be taxable on income generated by ownership of trust units so long as neither the property held by the trust nor the trust units are debt-financed property within the meaning of Section 514(b) of the Internal Revenue Code. In general, trust property would be debt-financed if the trust incurs debt to acquire the property or otherwise incurs or maintains a debt that would not have been incurred or maintained if the property had not been acquired and a trust unit would be debt-financed if the trust unitholder incurs debt to acquire the trust unit or otherwise incurs or maintains a debt that would not have been incurred or maintained if the trust unit had not been acquired.

        Non-U.S. Persons.    The trust (or the appropriate intermediary if units are held in "Street Name") intends to withhold on distributions paid to non-U.S. trust unitholders. The trust (or the appropriate intermediary if units are held in "Street Name") currently intends to withhold at the highest applicable effective tax rate. Non-U.S. trust unitholders should consult their own tax advisors with respect to seeking a refund for any portion of taxes withheld from distributions.

        As long as the trust units are regularly traded on an established securities market, gain realized by a non-U.S. trust unitholder on a sale of trust units will not be subject to U.S. federal income tax unless:

•

the gain is, or is treated as, effectively connected with business conducted by the non-U.S. trust unitholder in the United States, and in the case of an applicable tax treaty, is attributable to a U.S. permanent establishment maintained by the non-U.S. trust unitholder;



•

the non-U.S. trust unitholder is an individual who is present in the United States for at least 183 days in the year of the sale and certain other conditions are met; or



•

the non-U.S. trust unitholder owns currently, or owned at certain earlier times, directly or by applying certain attribution rules, more than 5% of the trust units.

Administrative Matters

        Trust Information Returns and Audit Procedures.    The trust intends to furnish to each trust unitholder, within 90 days after the close of each calendar year, specific tax information, including a Schedule K-1, which describes his share of the trust's income, gain, loss and deduction for the trust's preceding taxable year. In preparing this information, which will not be reviewed by counsel, the trust will take various accounting and reporting positions, some of which have been mentioned earlier, to determine each trust unitholder's share of income, gain, loss and deduction. The trust cannot assure unitholders that those positions will yield a result that conforms to the requirements of the Internal Revenue Code, Treasury Regulations or administrative interpretations of the IRS. Neither the trust nor Covington & Burling LLP can assure prospective trust unitholders that the IRS will not successfully contend in court that those positions are impermissible. Any challenge by the IRS could negatively affect the value of the units.

        The IRS may audit the trust's U.S. federal income tax information returns. Adjustments resulting from an IRS audit may require each trust unitholder to adjust a prior year's tax liability, and possibly may result in an audit of his return. Any audit of a trust unitholder's return could result in adjustments not related to the trust's returns as well as those related to the trust's returns.

        Partnerships generally are treated as separate entities for purposes of federal tax audits, judicial review of administrative adjustments by the IRS and tax settlement proceedings. The tax treatment of partnership items of income, gain, loss and deduction are determined in a partnership proceeding rather than in separate proceedings with the partners. The Internal Revenue Code requires that one

Table of Contents

partner be designated as the "Tax Matters Partner" for these purposes. The trust agreement names SandRidge E&P as the trust's Tax Matters Partner.

        The Tax Matters Partner has made and will make some elections on behalf of the trust and the trust unitholders. In addition, the Tax Matters Partner can extend the statute of limitations for assessment of tax deficiencies against trust unitholders for items in the trust's returns. The Tax Matters Partner may bind a trust unitholder with less than a 1% profits interest in the trust to a settlement with the IRS unless that trust unitholder elects, by filing a statement with the IRS, not to give that authority to the Tax Matters Partner. The Tax Matters Partner may seek judicial review, by which all the trust unitholders are bound, of a final partnership administrative adjustment and, if the Tax Matters Partner fails to seek judicial review, judicial review may be sought by any trust unitholder having at least a 1% interest in profits or by any group of trust unitholders having in the aggregate at least a 5% interest in profits. However, only one action for judicial review will go forward, and each trust unitholder with an interest in the outcome may participate.

        A trust unitholder must file a statement with the IRS identifying the treatment of any item on his federal income tax return that is not consistent with the treatment of the item on the trust's return. Intentional or negligent disregard of this consistency requirement may subject a trust unitholder to substantial penalties.

        Nominee Reporting.    Persons who hold an interest in the trust as a nominee for another person are required to furnish to the trust:

        (a)   the name, address and taxpayer identification number of the beneficial owner and the nominee;

        (b)   whether the beneficial owner is:

          (i)  a person that is not a United States person;

         (ii)  a non-U.S. government, an international organization or any wholly owned agency or instrumentality of either of the foregoing; or

        (iii)  a tax-exempt entity;

        (c)   the amount and description of units held, acquired or transferred for the beneficial owner; and

        (d)   specific information including the dates of acquisitions and transfers, means of acquisitions and transfers and acquisition cost for purchases, as well as the amount of net proceeds from sales.

        Brokers and financial institutions are required to furnish additional information, including whether they are United States persons and specific information on units they acquire, hold or transfer for their own account. A penalty of $100 per failure, up to a maximum of $1,500,000 per calendar year, is imposed by the Internal Revenue Code for failure to report that information to the trust. The nominee is required to supply the beneficial owner of the trust units with the information furnished to the trust.

        Accuracy-Related Penalties.    An additional tax equal to 20% of the amount of any portion of an underpayment of tax that is attributable to one or more specified causes, including negligence or disregard of rules or regulations, substantial understatements of income tax and substantial valuation misstatements, is imposed by the Internal Revenue Code. No penalty will be imposed, however, for any portion of an underpayment if it is shown that there was a reasonable cause for that portion and that the taxpayer acted in good faith regarding that portion.

        For individuals, a substantial understatement of income tax in any taxable year exists if the amount of the understatement exceeds the greater of 10% of the tax required to be shown on the return for

Table of Contents

the taxable year or $5,000. The amount of any understatement subject to penalty generally is reduced if any portion is attributable to a position adopted on the return:

        (1)   for which there is, or was, "substantial authority"; or

        (2)   as to which there is a reasonable basis and the pertinent facts of that position are disclosed on the return.

        If any item of income, gain, loss or deduction included in the distributive shares of trust unitholders might result in that kind of an "understatement" of income for which no "substantial authority" exists, the trust must disclose the pertinent facts on its return. In addition, the trust will make a reasonable effort to furnish sufficient information for trust unitholders to make adequate disclosure on their returns and to take other actions as may be appropriate to permit trust unitholders to avoid liability for this penalty. More stringent rules apply to "tax shelters," which the trust does not believe includes it, or any of the trust's investments, plans or arrangements.

        A substantial valuation misstatement exists if (a) the value of any property, or the tax basis of any property, claimed on a tax return is 150% or more of the amount determined to be the correct amount of the valuation or tax basis, (b) the price for any property or services (or for the use of property) claimed on any such return with respect to any transaction between persons described in Internal Revenue Code Section 482 is 200% or more (or 50% or less) of the amount determined under Section 482 to be the correct amount of such price, or (c) the net Internal Revenue Code Section 482 transfer price adjustment for the taxable year exceeds the lesser of $5 million or 10% of the taxpayer's gross receipts.

        No penalty is imposed unless the portion of the underpayment attributable to a substantial valuation misstatement exceeds $5,000 ($10,000 for most corporations). The penalty is increased to 40% in the event of a gross valuation misstatement. The trust does not anticipate making any valuation misstatements.

        Reportable Transactions.    If the trust were to engage in a "reportable transaction," the trust (and possibly the unitholders) would be required to make a detailed disclosure of the transaction to the IRS. A transaction may be a reportable transaction based upon any of several factors, including the fact that it is a type of tax avoidance transaction publicly identified by the IRS as a "listed transaction" or that it produces certain kinds of losses for partnerships, individuals, S corporations, and trusts in excess of $2 million in any single year, or $4 million in any combination of 6 successive tax years. The trust's participation in a reportable transaction could increase the likelihood that the trust's U.S. federal income tax information return (and possibly the unitholders' tax return) would be audited by the IRS. Please read "—Trust Information Returns and Audit Procedures."

        Moreover, if the trust were to participate in a reportable transaction with a significant purpose to avoid or evade tax, or in any listed transaction, unitholders may be subject to the following provisions of the American Jobs Creation Act of 2004:

•

accuracy-related penalties with a broader scope, significantly narrower exceptions, and potentially greater amounts than described above at "—Accuracy-Related Penalties";



���

for those persons otherwise entitled to deduct interest on federal tax deficiencies, non-deductibility of interest on any resulting tax liability; and



•

in the case of a listed transaction, an extended statute of limitations.

        The trust does not expect to engage in any "reportable transactions."

Table of Contents

STATE TAX CONSIDERATIONS

        The following is intended as a brief summary of certain information regarding state income taxes. No opinion of counsel has been requested or received with respect to the state tax consequences of an investment in trust units. Trust unitholders are urged to consult their own legal and tax advisors with respect to these matters.

        Prospective investors should consider state and local income tax consequences of an investment in the common units. The Royalty Interests owned by the trust burden specified oil and natural gas properties located in Alfalfa, Garfield, Grant, Major and Woods counties in Oklahoma. If the trust is treated as a partnership for U.S. federal income tax purposes, it will also be treated as a partnership for Oklahoma income tax purposes. Trust unitholders will be subject to Oklahoma income tax on all trust royalty income allocable to the unitholders; accordingly, trust unitholders will be required to file Oklahoma state income tax returns and pay taxes in Oklahoma, and may be subject to penalties for failure to comply with such requirements. The highest marginal rates for the payment of Oklahoma state income taxes are 5.25% for individuals, trusts and estates, and 6% for corporations. Generally, Oklahoma taxpayers are entitled to a depletion allowance on oil and natural gas income for state income tax purposes equal to the greater of cost depletion or percentage depletion, with the percentage depletion allowance for most taxpayers being 22%, but not in excess of 50% of the gross income from the property; however, each trust unitholder should consult their own legal and tax advisors to determine the Oklahoma depletion allowance specifically applicable to such unitholder. Although payments to out-of-state interest owners, including beneficial owners such as trust unitholders, in respect of Oklahoma oil and natural gas income generally are subject to withholding for Oklahoma income tax purposes at the rate of 5%, an exception exists for publicly traded partnerships that furnish detailed information concerning beneficial owners to the Oklahoma Tax Commission. The trust has furnished such information and intends to comply with those Oklahoma Tax Commission requirements as necessary to avoid withholding for Oklahoma state income tax purposes. Although Oklahoma municipalities are statutorily authorized to assess income taxes, no municipality has enacted such a tax. If any Oklahoma municipality were to enact an income tax, the tax could not be levied on nonresidents of the municipality.

Table of Contents

SELLING UNITHOLDER

        This prospectus covers the offering for resale or transfer common units by the selling unitholder. The selling unitholder acquired its units on April 12, 2011 in connection with the initial public offering of the trust's common units. The trust is registering the common units described below pursuant to a registration rights agreement entered into between the trust and SandRidge in connection with the initial public offering. See "Description of the Trust Units—Registration Rights."

        The selling unitholder may sell all, some or none of the common units covered by this prospectus. Please read "Plan of Distribution." No such sales may occur unless the registration statement of which this prospectus formsis a partpart.