Exhibit 99.3

				Deloitte & Touche LLP Suite 4500 1111 Bagby Street Houston, TX 77002-4196 USA Tel: +1 713 982 2000 Fax: +1 713 982 2001 www.deloitte.com

INDEPENDENT AUDITORS’ REPORT

To the Members of

Silver Hill Energy Partners, LLC:

We have audited the accompanying consolidated financial statements of Silver Hill Energy Partners, LLC (the “Company”), which comprise the consolidated balance sheets as of December 31, 2015 and 2014, and the related consolidated statements of operations, cash flows, members’ capital for the years then ended, and the related notes to the consolidated financial statements.

Management’s Responsibility for the Consolidated Financial Statements

Management is responsible for the preparation and fair presentation of these consolidated financial statements in accordance with accounting principles generally accepted in the United States of America; this includes the design, implementation, and maintenance of internal control relevant to the preparation and fair presentation of the consolidated financial statements that are free from material misstatement, whether due to fraud or error.

Auditors’ Responsibility

Our responsibility is to express an opinion on these consolidated financial statements based on our audits. We conducted our audits in accordance with auditing standards generally accepted in the United States of America. Those standards require that we plan and perform the audits to obtain reasonable assurance about whether the consolidated financial statements are free from material misstatement.

An audit involves performing procedures to obtain audit evidence about the amounts and disclosures in the consolidated financial statements. The procedures selected depend on the auditor’s judgment, including the assessment of the risks of material misstatement of the consolidated financial statements, whether due to fraud or error. In making those risk assessments, the auditor considers internal control relevant to the Company’s preparation and fair presentation of the consolidated financial statements in order to design audit procedures that are appropriate in the circumstances, but not for the purpose of expressing an opinion on the effectiveness of the Company’s internal control. Accordingly, we express no such opinion. An audit also includes evaluating the appropriateness of accounting policies used and the reasonableness of significant accounting estimates made by management, as well as evaluating the overall presentation of the consolidated financial statements.

We believe that the audit evidence we have obtained is sufficient and appropriate to provide a basis for our audit opinion.

Opinion

In our opinion, the consolidated financial statements referred to above present fairly, in all material respects, the financial position of Silver Hill Energy Partners, LLC as of December 31, 2015 and 2014, and the results of its operations and its cash flows for the year then ended in accordance with accounting principles generally accepted in the United States of America.

Emphasis of Matter

As discussed in Note 9 to the consolidated financial statements, the Company’s majority member has committed to support the Company for at least twelve months from April 30, 2016, to ensure the Company has sufficient liquidity to comply with the applicable debt covenants and normal operating requirements.

April 30, 2016 (October 11, 2016 as to the restatement discussed in Note 1)

SILVER HILL ENERGY PARTNERS, LLC

CONSOLIDATED BALANCE SHEETS

AS OF DECEMBER 31, 2015 AND 2014

See accompanying notes to these consolidated financial statements.

SILVER HILL ENERGY PARTNERS, LLC

CONSOLIDATED STATEMENTS OF OPERATIONS

FOR THE YEARS ENDED DECEMBER 31, 2015 AND 2014

See accompanying notes to these consolidated financial statements.

SILVER HILL ENERGY PARTNERS, LLC

CONSOLIDATED STATEMENTS OF MEMBERS’ CAPITAL

FOR THE YEARS ENDED DECEMBER 31, 2015 AND 2014

See accompanying notes to these consolidated financial statements.

SILVER HILL ENERGY PARTNERS, LLC

CONSOLIDATED STATEMENT OF CASH FLOWS

FOR THE YEARS ENDED DECEMBER 31, 2015 AND 2014

See accompanying notes to these consolidated financial statements.

SILVER HILL ENERGY PARTNERS, LLC

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

AS OF AND FOR THE YEARS ENDED DECEMBER 31, 2015 AND 2014

Organization—Silver Hill Energy Partners, LLC (the “Company”), a Delaware limited liability corporation, was formed on August 23, 2012. The Company’s activities have been primarily the evaluation and acquisition of various unproved leasehold interests and certain producing properties. The Company is engaged primarily in the acquisition, exploration, development and operation of oil and gas properties. Currently, the Company’s properties are in West Texas.

These financial statements include only those assets, liabilities, revenues and expenses that relate to the business of the Company and have been prepared in accordance with accounting principles generally accepted in the United States of America. The statements do not include any assets, liabilities, revenues or expenses attributable to the members’ individual activities.

The Company is a limited liability company (“LLC”). As an LLC, the amount of loss at risk for each individual member is limited to the amount of capital contributed to the LLC and, unless otherwise noted, the individual member’s liability for indebtedness of an LLC is limited to the member’s actual capital contribution.

Accounting Estimates—The preparation of the Company’s financial statements in conformity with accounting principles generally accepted in the United States of America requires the Company’s management to make estimates and assumptions that affect the amounts reported in these financial statements and accompanying notes. Certain significant estimates made by management include oil and gas reserves, which affect the carrying value of oil and gas properties, evaluation for impairment of proved and unevaluated property costs and asset retirement obligations. Actual results could differ from those estimates and the differences could be material.

Management believes that it is reasonably possible that the estimates involved in the determination of proved oil and gas reserves could significantly change in the coming year. Total proved reserves are defined as those reserves which can be produced economically using current oil and gas prices. Accordingly, the estimated quantity of proved reserves and the annual amortization expense will likely change along with future price increases and decreases.

Furthermore, estimating reserves is not an exact science. Estimates can be expected to change as additional information becomes available. Estimates of oil and gas reserves are projections based on the interpretation of engineering data to determine future rates of production and the timing of development expenditures. The accuracy of any reserve estimate is a function of the quality of available data and the engineering and geological

1

interpretation and judgment of the estimator. Accordingly, there can be no assurance that the reserves as estimated will ultimately be produced, nor can there be assurance that the proved undeveloped reserves as estimated will be developed within the period anticipated.

Cash and Cash Equivalents—Cash and cash equivalents include cash and all highly liquid investments with maturities, at the date of purchase, of three months or less. At times, the amount of cash and cash equivalents on deposit in financial institutions exceeds federally insured limits. Management monitors the soundness of the financial institutions and believes the Company’s risk is negligible.

Financial Instruments—The carrying amounts of financial instruments including cash and cash equivalents, accounts receivable, accounts payable and accrued liabilities approximate fair value, unless otherwise stated, as of December 31, 2015 and 2014.

Oil and Gas Properties—The Company’s oil and gas properties consisted of the following as of December 31, 2015 and 2014:

Subsequent to the issuance of the Company’s 2015 consolidated financial statements, an error was identified in the Company’s disclosure in the table above with regards to classification of mineral interest in oil and gas properties. This error resulted in the overstatement of the Company’s previously reported proved property balance of $46.2 million by $34.2 million and understatement of the previously reported unproved property balance of $35.5 million by the same amount as of December 31, 2015. The amounts disclosed in the table above have been revised to reflect the correct amount of proved and unproved properties. The error had no impact on any financial statement line item or other disclosures in the footnotes to the consolidated financial statements as of and for the years ended December 31, 2015 and 2014.

The Company follows the successful efforts method of accounting for oil and natural gas producing activities. Costs to acquire mineral interests in oil and natural gas properties, to drill and equip exploratory wells that find proved reserves, to drill and equip development wells and related asset retirement costs are capitalized. Costs to drill exploratory wells are capitalized pending determination of whether the wells have found proved reserves. If the Company determines that the wells do not find proved reserves, the costs are charged to expense. Geological and geophysical costs, including seismic studies and costs of

2

carrying and retaining unproved properties, are charged to expense as incurred. On the sale or retirement of a complete unit of a proved property, the cost and related accumulated depletion and depreciation are eliminated from the property accounts, and the resulting gain or loss is recognized. On the sale of a partial unit of proved property, the amount received is treated as a reduction of the cost of the interest retained.

The Company records depletion, depreciation and amortization of capitalized costs of proved oil and gas properties using the unit-of-production method over estimated proved reserves using the unit conversion ratio of six million cubic feet of gas to one barrel of oil equivalent. Capitalized costs of proved mineral interests are depleted over total estimated proved reserves, and capitalized costs of wells and related equipment and facilities are depreciated over estimated proved developed reserves. Depletion, depreciation and amortization expense for oil and gas properties amounted to $8.8 million and $4.8 million for the years ended December 31, 2015 and 2014, respectively.

Unproved oil and natural gas properties that are individually significant are periodically assessed for impairment of value, and a loss is recognized at the time of impairment by providing an impairment allowance. No impairment of unproved properties was recorded during the year ended December 31, 2015 and 2014 as the Company continues to extend its leases and complies with its lease terms through production and continuous development. The Company commenced its horizontal drilling strategy in December 2014 and has completed six economical well in 2015. Management also evaluated several recent transactions in the West Texas area and believes the terms support its carrying value as of December 31, 2015.

On the sale of an entire interest in an unproved property for cash or cash equivalent, gain or loss on the sale is recognized, taking into consideration the amount of any recorded impairment if the property had been assessed individually. If a partial interest in an unproved property is sold, the amount received is treated as a reduction of the cost of the interest retained.

Capitalized costs related to proved oil and natural gas properties, including wells and related equipment and facilities, are evaluated for impairment based on an analysis of undiscounted future net cash flows. If undiscounted cash flows are insufficient to recover the net capitalized costs related to proved properties, then an impairment charge is recognized in the Statement of Operations equal to the difference between the carrying value proved properties and their estimated fair values based on the present value of the related future net cash flows. The Company recorded impairment of $8.1 million and $13.8 million on proved properties for the years ended December 31, 2015 and 2014, respectively.

Furniture, Fixtures, and Equipment—Furniture, fixtures, and equipment are recorded at cost less accumulated depreciation. Depreciation of the related assets is provided using the straight-line method over their respective estimated useful lives.

3

When assets are sold or retired, the applicable costs and accumulated depreciation are removed and any gain or loss is included in income. Maintenance and repairs are expensed as incurred. Major renewals and improvements are capitalized.

Investment in joint venture—The Company’s 50% interest in the Midstream Joint Venture (Note 3) is not consolidated in the Company’s consolidated financial statements because the structural and operational measures of the Amended and Restated Limited Liability Company of the Midstream Joint Venture dated January 9, 2015 (the “LLC Agreement”) prevent us from having power to direct the significant activities of Midstream Joint Venture. In accordance with accounting standards, we account for our investment in the Midstream Joint Venture under the equity method, as opposed to the cost method, based on the Company’s level of influence over its activities. There are no other investments accounted for under the equity or cost method.

The Company recognizes its share of the earnings and losses in the Midstream Joint Venture pursuant to terms of the LLC Agreement which provides for earnings and losses to be generally allocated based upon each member’s respective ownership interest in the Midstream Joint Venture. See Note 3 for a discussion of the Company’s investment in the Midstream Joint Venture.

The Company evaluates investments for impairment when factors indicate that a decrease in the value of the investment has occurred that is not temporary. Indicators that should be evaluated for possible impairment of investments include recurring operating losses of the investee or fair value measures that are less than carrying value. Any impairment recognition is based on fair value that is not reflective of temporary conditions. Fair value is determined primarily by discounted long-term cash flows, supported by available market valuations, if applicable. The Company has not incurred impairment to its investment in the Midstream Joint Venture as of December 31, 2015.

Asset Retirement Obligation—Asset retirement obligations (“ARO”) consist of future plugging and abandonment expenses on oil and gas properties. The Company records the estimated fair value of its ARO when the related wells are acquired or completed with a corresponding increase in the carrying amount of oil and gas. The liability is accreted to its present value each period. Management estimates the fair value of additions to the asset retirement obligation liability using a valuation technique that converts future cash flows to a single discounted amount. Significant inputs to the valuation include: (i) estimated plug and abandonment cost per well based on management’s experience; (ii) estimated remaining life per well; and (iii) the Company’s credit-adjusted risk-free rate. If the liability is settled for an amount other than the recorded amount, a gain or loss is recognized.

The following is a summary of changes in the ARO during the years ended December 31, 2015 and 2014:

4

Revenue—The Company recognizes revenue for its production when the quantities are delivered to or collected by the respective purchaser. Prices for such production are defined in sales contracts and are readily determinable based on certain publicly available indices.

Lease Operating Costs—Lease operating costs, including pumpers’ salaries, saltwater disposal, ad valorem taxes, repairs and maintenance, expensed workovers and other operating expenses are expensed as incurred and included in lease operating costs on the consolidated statement of operations.

Concentration of Credit Risk— Substantially all accounts receivable result from the sales of oil and natural gas. This concentration of customers may impact the Company’s overall credit risk, as these entities may be similarly affected by changes in economic and other conditions. For the years ended December 31, 2015 and 2014, nearly all of the Company’s oil and natural sales were derived from two purchasers. These purchasers are based in the United States and engaged in the transportation, storage, and marketing of crude oil and other petroleum products. Management believes that the loss of these purchasers would not have a material adverse effect on the Company’s financial position or results of operations because there is an adequate number of potential other purchasers of its oil and gas production.

Income Taxes—The Company is subject to U.S. federal income tax reporting requirements along with state income tax reporting requirements in Texas. Because the Company is a limited liability company, the income or loss of the Company for federal income tax purposes is generally allocated to the members in accordance with the Company’s formation agreements, and it is the responsibility of the members to report their share of taxable income or loss on their separate income tax returns. Accordingly, no recognition has been given to federal income taxes in the accompanying financial statements. The Company is subject to Texas margin tax on its operations within the state of Texas, and such amount is included in income tax expense on the Company’s statement of operations. Based on management’s analysis, the Company did not have any uncertain tax positions as of December 31, 2015 and 2014. No interest and penalties have been accrued or recorded. Currently, the tax year of 2013, 2014 and 2015 are open for reviews by the applicable taxing authorities.

The Company provides deferred income taxes using the liability method whereby deferred tax assets are recognized for deductible temporary differences and operating loss, and tax credit carryforwards and deferred tax liabilities are recognized for taxable temporary differences. Temporary differences are the differences between the reported amounts of assets and liabilities and their tax bases. Deferred tax assets are reduced by a

5

valuation allowance when, in the opinion of management, it is more likely than not that some portion or all of the deferred tax assets will not be realized. Deferred tax assets and liabilities are adjusted for the effects of the changes in tax laws and rates on the date of enactment.

Recently Issued Accounting Standards

The FASB issued ASU 2014-09, Revenue from Contracts with Customers (Topic 606). This ASU supersedes the revenue recognition requirements in Topic 605, Revenue Recognition and industry-specific guidance in Subtopic 932-605, Extractive Activities – Oil and Gas – Revenue Recognition. This ASU provides guidance concerning the recognition and measurement of revenue from contracts with customers. Its objective is to increase the usefulness of information in the financial statements regarding the nature, timing and uncertainty of revenues. This standard becomes effective for us beginning January 2018. The Company is evaluating the impact this ASU may have on our consolidated financial statements and related disclosures.

The FASB issued ASU 2015-02, Consolidation (Topic 810): Amendments to the Consolidation Analysis. This ASU provides additional guidance to reporting entities in evaluating whether certain legal entities, such as limited partnerships, limited liability corporations and securitization structures, should be consolidated. The ASU reduces the number of existing consolidation models. This ASU is effective for us beginning January 2016. This ASU is not expected to have a material impact on us.

The FASB issued ASU 2015-03, Interest – Imputation of Interest (Topic 835): Simplifying the Presentation of Debt Issuance Costs and ASU 2015-15, Interest – Imputation of Interest (Topic 835): Presentation and Subsequent Measurement of Debt Issuance Costs Associated with Line-of-Credit Arrangements. These ASUs require debt issuance costs to be presented as a direct deduction from the carrying amount of that debt rather than as an asset. These ASUs are effective for us beginning January 2016. These ASUs will not have a material impact on our consolidated financial statements and related disclosures.

On June 10, 2014, the Company purchased producing and non-producing oil and gas properties in Loving and Winkler County, Texas for cash consideration of $17.0 million for which $15.6 million and $1.4 million were allocated to unproved and proved, respectively, and was accounted for as a purchase of assets.

On January 9, 2015, the Company closed commercial agreements between a newly formed, wholly owned subsidiary, Silver Hill Midstream, LLC and a third party (together, the “Members”) to form a joint venture with the purpose of constructing and operating midstream assets in Loving, Winkler, Ward, and Reeves Counties, Texas and Lea County, New Mexico (the “Midstream Joint Venture”).

6

On January 9, 2015, the Company contributed $3.6 million in cash and assets with attributable value of $0.2 million and the other Member contributed midstream assets with an attributable value of $3.3 million and cash of $0.5 million (the “Initial Contribution”) to initiate the capitalization of the Midstream Joint Venture as prescribed in the Investment Agreement dated as of January 9, 2015 (the “Investment Agreement”). During the year ended December 31, 2015, the Company’s total cash contribution to the Midstream Joint Venture was $37.4 million. The Midstream Joint Venture had minimal operation in 2015 as the core midstream assets were being constructed. The Company recognized its 50% share of equity losses in the Midstream Joint Ventures of $0.5 million and did not receive any dividends for the year ended December 31, 2015. The Company does not have a difference between the carrying value of its investments and the Company’s underlying equity in the net assets of the Midstream Joint Venture.

The Company has concluded that the Midstream Joint Venture is a joint venture as it’s a separate and specific business and provides an arrangement under which the Members may participate, directly or indirectly, in the overall management and share equally in the risks and rewards of the joint venture. The Members each have joint control and neither has unilateral control over the power to direct the significant activities and neither of the Midstream Joint Venture. Each Member has two voting board seats, providing joint and equal control of the decisions of the Midstream Joint Venture. The Members are required to approve business plans, annual budgets and revisions, as well as changes in board members and officers of the Midstream Joint Venture.

The Company has elected to account for its investments in the Midstream Joint Venture under the equity method of accounting since it has significant influence and not control over the operating and financing decisions of the Midstream Joint Venture. The Company measures its investments initially at cost and then recognizes its share of the earnings or losses as reported in the financial statements of the Midstream Joint Venture which is included in the determination of the Company’s net income adjusted for any intra-entity profits and losses.

The summarized balance sheet and statement of operations of the Midstream Joint Venture is as follows:

7

On July 10, 2015, the Company entered into a new $250.0 million Revolving Credit Agreement (“RBL”) with Wells Fargo Bank. The reserve-based facility features a borrowing base equal to the greater of a fixed amount of $17.5 million or a variable amount based upon the value of the Company’s oil and gas reserves as assessed by Wells Fargo Bank. The assessment of the Company’s oil and gas reserves is redetermined biannually in April and October. The RBL has a scheduled maturity date of July 10, 2020. The RBL has a variable annual interest rate based on the Company’s option, either the London InterBank Offered Rate (“LIBOR”) plus an applicable margin (Eurodollar rate) or the base rate (as defined in the Agreement) plus an applicable margin. In addition, a commitment fee between 0.375% and 0.5% per annum is charged on the unutilized balance of the committed borrowings. Debt issuance costs of incurred totaled $0.2 million during 2015. The terms of the RBL contains representations, warranties, covenants and events of default that are customary for investment-grade, commercial bank credit agreements.

In October 2015, Wells Fargo Bank redetermined the Company’s borrowing based under the RBL and increased the variable amount to $29.0 million. For the year ended December 31, 2015, the Company had drawn $25.0 million in borrowings under the RBL.

The LLC agreement dated September 6, 2012 governs the Company’s ownership. Capital contributions from Members during the years ended December 31, 2015 and 2014 were used to fund the Company’s ongoing operating and investing activities including the purchase of assets explained in Note 2.

Net income or loss and distributions are allocated among the members as follows:

8

The Company leases office space under noncancellable operating leases. Total rental expense was $247,862 and $211,582 for the years ended December 31, 2015 and 2014, respectively. The future minimum rental commitments as of December 31, 2015 are as follows:

We are party to various legal actions arising in the normal course of business. Management believes the disposition of these outstanding legal actions will not have a material impact on our financial condition, results of operations or cash flows.

The Company engages in price risk management activities from time to time. These activities are intended to manage the Company’s exposure to fluctuations in commodity prices for crude oil and natural gas. The Company utilized financial commodity derivative instruments including swaps and collars, as a means to manage this price risk.

During 2015, the Company elected not to designate any of its financial commodity derivative contracts as accounting hedges and, accordingly, accounted for these financial commodity derivative contracts using the mark-to-market accounting method. During 2015, the Company recognized unrealized gains on the mark-to-market of financial commodity derivative contracts of $2.5 million and realized gains of $0.4 million on cash settled crude oil derivative contracts.

US GAAP establishes a fair value hierarchy that prioritizes the inputs used to measure fair value. The hierarchy gives the highest priority to unadjusted quoted prices in active markets for identical assets or liabilities (Level 1 measurement) and lowest priority to unobservable inputs (Level 3 measurement).

9

The three levels of fair value hierarchy are as follows:

The following table provided fair value measurement information within the fair value hierarchy for certain of the Company’s financial assets carried at fair value on a recurring basis at December 31, 2015. Amounts shown in thousands.

Fair Value Measurements

The estimated fair value of crude oil derivative contracts was based upon forward commodity price curves based on quoted market prices. Commodity derivative contracts were valued by Wells Fargo Bank.

The following summarizing our commodity derivative positions as of December 31, 2015:

SWAPS

10

COLLARS

Nonrecurring Fair Value Measurements—Certain nonfinancial assets and liabilities are measured at fair value on a nonrecurring basis (e.g., oil and natural gas properties) and are subject to fair value adjustments under certain circumstances. The inputs used to determine such fair value are primarily based upon internally developed cash flow models and are classified within Level 3.

During the years ended December 31, 2015 and 2014, using a discounted cash flow valuation technique, we adjusted the carrying value of certain oil and natural gas properties and recorded impairment charges of $8.1 million and $13.8 million, respectively. The impairment charges primarily resulted from a decline in oil and natural gas prices and to a much lesser extent to minor changes in management’s assumptions, based on an extensive review of operating results, production history, price realizations and costs.

The Company paid $860.9 thousand to a related party for lease operating work performed by that related party during the year ended December 31, 2015 of which $75.5 thousand was included in accounts payable as of December 31, 2015.

Our business exposes us to certain risks associated with the development of crude oil, natural gas, and natural gas liquids (“NGLs”) which could have a material adverse effect on our cash flows, operations and liquidity, including, but not limited to: the market price and demand for crude oil, natural gas, and NGLs, fluctuations in the production of crude oil, natural gas, and NGLs, fluctuations in drilling and development activity, and credit risk associated with customers.

We have incurred significant losses from operations and we have utilized primarily capital contributions from our Members to fund our operations, capital requirements, and acquisitions, and to remain in compliance with debt covenants under the RBL (see Note 4). For the years ended December 31, 2015 and 2014, we incurred a net loss of approximately $9.9 million and $22.9 million, respectively.

We have continued to strategically develop our Delaware Basin asset by drilling and completing superior IRR wells, while also taking advantage of acquisition opportunities as they arise. The Company has primarily relied upon capital contributions from our Members to fund operations, acquisitions, and to remain in compliance with debt covenants under the RBL (see Note 4). Without support from our Members, compliance with our debt covenants during 2016 may not remain possible.

11

Compliance with debt covenants, and the long-term continuation of our business plan, including capital expenditures to acquire and develop oil and gas properties in 2016 and beyond, is dependent upon support and capital contributions from our Members. Failure to obtain additional capital through our Members could have a material adverse effect on our ability to meet our long-term liquidity needs and achieve our intended long-term business objectives.

In response to the Company’s expected need for additional liquidity, our Majority Member has committed to provide the necessary funding to support the Company for at least twelve months from April 30, 2016, to ensure the Company has sufficient liquidity to comply with our applicable debt covenants and normal operating requirements. Therefore, our financial statements have been presented as if the Company will continue as a going concern.

On February 26, 2016 Silver Hill Energy Partners, LLC entered into a Management Services Agreement with Silver Hill Energy Partners II, LLC to provide certain operational and general and administrative services with respect to Silver Hill Energy Partners II, LLC’s Delaware Basin assets.

No other subsequent events were assessed through April 30, 2016, the date this report was available for issuance.

* * * * * *

12