Exhibit 99



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February 15, 2013

Corporate Trust Division

Trustee, BP Prudhoe Bay Royalty Trust

The Bank of New York Mellon Trust Company, N.A.

919 Congress Avenue, Suite 500

Austin, Texas
78701

Attn: Mr. Michael Ulrich, Vice President



| | Re: | Estimates of Proved Reserves, Future Production Rates, and Future Net Revenues for the BP Prudhoe Bay Royalty Trust As of December 31, 2012
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Gentlemen:

This letter report is a summary of investigations performed in accordance with the Miller and Lents, Ltd. (MLL) engagement by you as described in Section 4.8(d) of the Overriding Royalty Conveyance
dated February 27, 1989, between BP Exploration (Alaska) Inc. and The Standard Oil Company. The purpose of MLLs review was to determine that the procedures and methods used by BP Exploration (Alaska) Inc. are effective and in accordance
with the definitions contained in the Securities and Exchange Commission Regulation S-X, Rule 4-10(a). The investigations included reviews of the estimates of Proved Reserves and production rate forecasts of oil and condensate made by BP Exploration
(Alaska) Inc. attributable to the BP Prudhoe Bay Royalty Trust (Trust) as of December 31, 2012. Additionally, MLL reviewed calculations of the resulting Estimated Future Net Revenues and Present Value of Estimated Future Net Revenues
attributable to the BP Prudhoe Bay Royalty Trust. MLLs review covers 100 percent of reserves and revenues attributable to the BP Prudhoe Bay Royalty Trust.

The estimates and calculations reviewed were summarized in the report prepared by BP Exploration (Alaska) Inc. and transmitted with a cover letter dated February 7, 2013 addressed to Mr. Michael
Ulrich of The Bank of New York Mellon Trust Company, N.A. and signed by Mr. Mark Wichman. Reviews were also performed by Miller and Lents, Ltd. during this year or in previous years of (1) the procedures for estimating and documenting
Proved Reserves, (2) the estimates of in-place reservoir volumes, (3) the estimates of recovery factors and production profiles for the various areas, pay zones, projects, and recovery processes that are included in the estimate of Proved
Reserves, (4) the production strategy and procedures for implementing that strategy, (5) the sufficiency of the data available for making estimates of Proved Reserves and production profiles, and (6) pertinent provisions of the
Prudhoe Bay Unit Operating Agreement, the



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|The Bank of New York Mellon Trust Company, N.A. |  |  | February 15, 2013 | 
|Trustee, BP Prudhoe Bay Royalty Trust           |  |  | Page 2            | 

Issues Resolution Agreement, the Overriding Royalty Conveyance, the Trust Conveyance, the BP Prudhoe Bay Royalty Trust
Agreement, and other related documents referenced in the Form F-3 Registration Statement filed with the Securities and Exchange Commission (SEC) on August 7, 1989 by BP Exploration (Alaska) Inc.

Proved Reserves were estimated by BP Exploration (Alaska) Inc. in accordance with the definitions contained in Securities and Exchange
Commission Regulation S-X, Rule 4-10(a). Estimated Future Net Revenues and Present Value of Estimated Future Net Revenues are not intended and should not be interpreted to represent fair market values for the estimated reserves.

The Prudhoe Bay (Permo-Triassic) Reservoir is defined in the Prudhoe Bay Unit Operating Agreement. The Prudhoe Bay Unit is an oil and gas
unit situated on the North Slope of Alaska. The BP Prudhoe Bay Royalty Trust is entitled to a royalty payment on 16.4246 percent of the first 90,000 barrels of the actual average daily net production of oil and condensate for each calendar
quarter from the BP Exploration (Alaska) Inc. working interest as defined in the Overriding Royalty Conveyance. The payment amount depends upon the per barrel Royalty that in turn depends upon the West Texas Intermediate Price, the Chargeable Costs,
the Cost Adjustment Factor, and Production Taxes, all of which are defined in the Overriding Royalty Conveyance. Barrel as used herein means Stock Tank Barrel as defined in the Overriding Royalty Conveyance.

Payments received by the Trust are based exclusively on a percentage of the first 90,000 barrels of the average actual daily net
production of crude oil and condensate from the leases subject to the Overriding Royalty Conveyance. There is no relationship between any delivery commitments of BP Exploration (Alaska) and the other owners of the working interests in the
Prudhoe Bay Field and the Trusts entitlement to the prescribed royalty payments. The Trust does not directly or indirectly own any working interests in wells, operations, or acreage.

MLLs reviews do not constitute independent estimates of the reserves and annual production rate forecasts for the areas, pay zones,
projects, and recovery processes examined. MLL relied upon the accuracy and completeness of information provided by BP Exploration (Alaska) Inc. with respect to pertinent ownership interests and various other historical, accounting, engineering, and
geological data. MLL employed all methods, procedures, and assumptions considered necessary in utilizing the data provided to prepare this report.

As a result of our cumulative reviews, based on the foregoing, MLL concludes that:



| | 1. | A large body of basic data and detailed analyses are available and were used in making the estimates. In MLLs judgment, the quantity and quality of currently
available data on reservoir boundaries, original fluid contacts, and reservoir rock and fluid properties are sufficient to indicate that any future revisions to the estimates of total original in-place volumes should be minor. Furthermore, the data
and analyses on recovery factors and future production rates are sufficient to support the Proved Reserves estimates.
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| | 2. | Proved Reserves were estimated generally by extrapolation of well-established historical production performance trends and/or were supported by other geologic and
engineering studies. Where sufficient performance data did not exist, reserves were estimated by volumetric calculations, simulations, or by analogy to similar producing areas of the field. The methods and procedures employed to accumulate and
evaluate the necessary information and to estimate, document, and reconcile reserves, annual production rate forecasts, and future net revenues are effective and appropriate.
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| | 3. | Based on MLLs limited independent tests of the computations of reserves, production profiles, and future net revenues, such computations were performed in
accordance with the methods and procedures described to us and conform to the relevant SEC definitions.
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| | 4. | The estimated net remaining Proved Reserves attributable to the BP Prudhoe Bay Royalty Trust as of December 31, 2012 of 75.517 million barrels of oil and
condensate are, in the aggregate, reasonable. Of the 75.517 million barrels of total Proved Reserves, 70.676 million barrels are Proved Developed Reserves, and 4.841 million barrels are Proved Undeveloped Reserves.
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| | 5. | The 2012 average West Texas Intermediate Price of $94.71 per barrel, applicable under current SEC regulations, represents the 12-month average of the
first-day-of-the-month price for each month within the 12-month period prior to December 31, 2012. Based on this price, other economic parameters as prescribed by the Overriding Royalty Conveyance, and utilizing the specified procedures
outlined in Financial Accounting Standards Board Accounting Standards Codification 932, Extractive Activities  Oil and Gas, BP Exploration (Alaska) Inc. calculated that as of December 31, 2012 production of the Proved Reserves will
result in Estimated Future Net Revenues of $2,176.0 million and Present Value of Estimated Future Net Revenues of $1,314.9 million to the BP Prudhoe Bay Royalty Trust. These estimates are reasonable.
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| | 6. | As a consequence of the natural production decline and the downtime required for ongoing infrastructure and other improvements, BP Exploration (Alaska) Inc.s net
production of oil and condensate from Proved Reserves attributable to the Trust was less than 90,000 barrels per day on an annual average basis in 2012. BP Exploration (Alaska) Inc. expects that its net production of oil and condensate from Proved
Reserves attributable to the Trust will be less than 90,000 barrels per day on an average basis for most future years. The BP Exploration (Alaska) Inc. projection of its future net production of oil and condensate is reasonable.
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| | 7. | Production attributable to the BP Prudhoe Bay Royalty Trust will decline with the BP Exploration (Alaska) Inc. production. However, the per barrel Royalty will not have
a positive value if the West Texas Intermediate Price is less than the sum of the per barrel Chargeable Costs and per barrel Production Taxes, appropriately adjusted in accordance with the Overriding Royalty Conveyance. Under such circumstances,
average daily production attributable to the BP Prudhoe Bay Royalty Trust will have no value and therefore will not contribute to the reserves regardless of BP Exploration (Alaska) Inc.s net production level.
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| | 8. | Based on the SEC-defined 12-month average West Texas Intermediate Price of $94.71 per barrel and Production Taxes and Adjusted Chargeable Costs as prescribed by the
Overriding Royalty Conveyance, the projection that royalty payments will continue through the year 2029 is reasonable. For the economic conditions and production forecast as of December 31, 2012 the per barrel Royalty will be zero following the
year 2029. Therefore, no reserves are currently attributed to the BP Prudhoe Bay Royalty Trust after that date. The cessation of production date forecasted by BP Exploration (Alaska) Inc. exceeds the life of the Prudhoe Bay Royalty Trust.
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| | 9. | Even if expected reservoir performance does not change, the estimated reserves, economic life, and future revenues attributable to the BP Prudhoe Bay Royalty Trust may
change significantly in the future. This may result from changes in the West Texas Intermediate Price or from changes in other prescribed variables utilized in calculations defined by the Overriding Royalty Conveyance.
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Estimates of ultimate and remaining reserves and production scheduling depend upon assumptions regarding expansion or implementation of
alternative projects or development programs and upon strategies for production optimization. BP Exploration (Alaska) Inc. has continual reservoir management, surveillance, and planning efforts dedicated to (1) gathering new information,
(2) improving the accuracy of its reserves and production capacity estimates, (3) recognizing and exploiting new opportunities, (4) anticipating potential problems and taking corrective actions, and (5) identifying, selecting,
and implementing optimum recovery program and cost reduction alternatives. Given this significant effort and ever-changing economic conditions, estimates of reserves and production profiles will change periodically.

The current estimate of Proved Reserves includes volumes of Proved Undeveloped Reserves that are part of ongoing development activities
for which BP Exploration (Alaska) Inc. has a historical track record of completing comparable projects. Approximately 2.189 million barrels (net) of Proved Undeveloped Reserves attributable to the Trust were converted into Proved Developed
Reserves during 2012 and approximately 0.158 million barrels (net) of Proved Undeveloped Reserves attributable to the Trust were added during 2012 as a result of planned projects. In all cases, the volumes are being progressed as part of an
adopted development plan that calls for drilling of wells over an extended period of time given the magnitude of the development. There were no contributions to Proved Undeveloped Reserves from extensions or discoveries during 2012.

Future projects, development programs, or operating strategies different from those assumed in the current estimates may change future
estimates and affect recoveries. However, because several complementary and alternative projects are being considered for recovery of the remaining oil in the reservoir, a decision not to implement a currently planned project may allow scope
expansion or implementation of another project, thereby increasing the overall likelihood of recovering the reserves.



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Future production rates will be controlled by
facilities limitations and upsets, well downtime, and the effectiveness of programs to optimize production and costs. Additional drilling, workovers, facilities modifications, new recovery projects, and programs for production enhancement and
optimization are expected to mitigate but not eliminate the decline in gross oil and condensate production capacity.

In
making its future production rate forecasts, BP Exploration (Alaska) Inc. provided for anticipated downtime and planned facilities upsets. Although allowances for unplanned upsets are also considered in the estimates, the studies do not provide for
any impediments to crude oil production as a consequence of major disruptions.

Under current economic conditions, gas from
the Alaskan North Slope, except for minor volumes, cannot be marketed commercially. Oil and condensate recoveries are expected to be greater as a result of continued reinjection of produced gas than the recoveries would be if major volumes of
produced gas were being sold. No major gas sale is assumed in the current estimates. In the event that major gas sales are initiated, ultimate oil and condensate recoveries may be reduced from the current estimates unless recovery projects other
than those included in the current estimates are implemented.

Large volumes of natural gas liquids are likely to be produced
and marketed in the future whether or not major gas sales become viable. Natural gas liquids reserves are not included in the estimates cited herein. The BP Prudhoe Bay Royalty Trust is not entitled to royalty payments from production or sales of
natural gas or natural gas liquids.

The evaluations presented in this report, with the exceptions of those parameters
specified by others, reflect MLLs informed judgments and are subject to the inherent uncertainties associated with interpretation of geological, geophysical, and engineering information. These uncertainties include, but are not limited to the
(1) utilization of analogous or indirect data and (2) application of professional judgment. At this time, MLL and BP Exploration (Alaska) Inc. are not aware of any existing or pending federal or state regulations that would materially
affect the ability of BP Exploration (Alaska) Inc. to recover the estimated reserves in the Prudhoe Bay Field. Government policies and market conditions different from those reflected in this study or disruption of existing transportation routes or
facilities may cause (1) the total quantity of oil or condensate to be recovered, (2) actual production rates, (3) prices received, or (4) operating and capital costs to vary from those reviewed in this report.

Miller and Lents, Ltd. was founded in 1948, offering services and expertise in many phases of the oil and gas industry. The firm is
registered with the Texas Board of Professional Engineers. The engineering staff members assigned to the BP Prudhoe Bay Royalty Trust project are all university graduates, with degrees in petroleum engineering and/or advanced degrees in petroleum or
chemical engineering. All are licensed professional engineers with over 25 years of diversified experience, including at least 10 years of experience with the BP Prudhoe Bay Royalty Trust.

Miller and Lents, Ltd. is an independent oil and gas consulting firm. No director, officer, or key employee of Miller and Lents, Ltd. has
any financial ownership in the BP Prudhoe Bay Royalty Trust, BP Exploration (Alaska) Inc. or its parent or any related companies. Our fee is not contingent upon the results of



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|The Bank of New York Mellon Trust Company, N.A.
Trustee, BP Prudhoe Bay Royalty Trust |  |  | February 15, 2013Page
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our work or report, and we have not performed other services for BP Exploration (Alaska) Inc. or the BP Prudhoe Bay
Royalty Trust that would affect our objectivity. Miller and Lents, Ltd. hereby grants consent for use of this letter, in its entirety, in the BP Prudhoe Bay Royalty Trusts SEC Form 10-K annual report filing for the fiscal year ended
December 31, 2012.



Very truly yours,LOGO


WPK/CDR/RJO/eb