Exhibit 99.1
 
  
 Re:
    
    Ramshorn Investments, Inc.Proved Reserves andFuture Net RevenuesAs of December 31, 2010SEC Price Case
   Reserves and Future Net Revenues as of December 31, 2010
 Net Reserves
    
    Future Net RevenuesDiscounted atLiquids,
    
    Gas,
    
    Undiscounted,
    
    10% Per Year,Reserves Category
    
    MBbls.
    
    MMcf
    
    M$
    
    M$Proved Producing
    
    
    213.0
    
    
    
    14,906.3
    
    
    
    38,594.0
    
    
    
    20,972.0Proved Nonproducing
    
    
    53.8
    
    
    
    2,146.2
    
    
    
    8,224.0
    
    
    
    4,449.7Total Proved Developed
    
    
    266.8
    
    
    
    17,052.5
    
    
    
    46,818.0
    
    
    
    25,421.7Proved Undeveloped
    
    
    22.4
    
    
    
    2,715.2
    
    
    
    7,097.3
    
    
    
    2,335.6Total Proved
    
    
    289.2
    
    
    
    19,767.7
    
    
    
    53,915.3
    
    
    
    27,757.3
  Two Houston Center  909 Fannin Street, Suite 1300  Houston, Texas 77010  Telephone 713-651-9455
 Telefax 713-654-9914 e-mail: mail@millerandlents.com




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Mr. Shawn McWilliams
    
    January 10, 2011Ramshorn Investments, Inc.
    
    Page 2
   Production Data
  Prices




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Mr. Shawn McWilliams
    
    January 10, 2011Ramshorn Investments, Inc.
    
    Page 3
  Operating Costs
  Ownership Interests
   Reserves Projections




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Mr. Shawn McWilliams
    
    January 10, 2011Ramshorn Investments, Inc.
    
    Page 4
 Attachments
    Other Considerations




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Mr. Shawn McWilliams
    
    January 10, 2011Ramshorn Investments, Inc.
    
    Page 5
   Very truly yours,MILLER AND LENTS, LTD.Texas Registered Engineering Firm No. F-1442By
    

-s- Carl D. Richard, P.E.
Carl D. Richard, P.E.Senior Vice President(SEAL)




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Appendix
Page 1 of 3
 Reserves Definitions In Accordance With  Securities and Exchange Commission Regulation S-X
 Reserves
   Proved Oil and Gas Reserves
  1.
    
    The area of the reservoir considered as proved includes:
 a.
    
    The area identified by drilling and limited by fluid contacts, if any, andb.
    
    Adjacent undrilled portions of the reservoir that can, with
reasonable certainty, be judged to be continuous with it and to contain
economically producible oil or gas on the basis of available geoscience and
engineering data.
 2.
    
    In the absence of data on fluid contacts, proved quantities in a reservoir
are limited by the lowest known hydrocarbons (LKH) as seen in a well penetration
unless geoscience, engineering, or performance data and reliable technology
establishes a lower contact with reasonable certainty.3.
    
    Where direct observation from well penetrations has defined a highest known
oil (HKO) elevation and the potential exists for an associated gas cap, proved oil
reserves may be assigned in the structurally higher portions of the reservoir only
if geoscience, engineering, or performance data and reliable technology establish
the higher contact with reasonable certainty.4.
    
    Reserves which can be produced economically through application of improved
recovery techniques (including, but not limited to, fluid injection) are included in
the proved classification when:
 a.
    
    Successful testing by a pilot project in an area of the reservoir
with properties no more favorable than in the reservoir as a whole, the
operation of an installed program in the reservoir or an analogous reservoir,
or other evidence using reliable technology establishes the reasonable
certainty of the engineering analysis on which the project or program was
based; andb.
    
    The project has been approved for development by all necessary
parties and entities, including governmental entities.




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Appendix
Page 2 of 3
 5.
    
    Existing economic conditions include prices and costs at which economic
producibility from a reservoir is to be determined. The price shall be the
average price during the 12-month period prior to the ending date of the period
covered by the report, determined as an unweighted arithmetic average of the
first-day-of-the-month price for each month within such period, unless prices
are defined by contractual arrangements, excluding escalations based upon future
conditions.
 Developed Oil and Gas Reserves
  1.
    
    Through existing wells with existing equipment and operating methods or in
which the cost of the required equipment is relatively minor compared to the cost of
a new well; and2.
    
    Through installed extraction equipment and infrastructure operational at the
time of the reserves estimate if the extraction is by means not involving a well.
 Undeveloped Oil and Gas Reserves
  1.
    
    Reserves on undrilled acreage shall be limited to those directly offsetting
development spacing areas that are reasonably certain of production when drilled,
unless evidence using reliable technology exists that establishes reasonable
certainty of economic producibility at greater distances.2.
    
    Undrilled locations can be classified as having undeveloped reserves only if
a development plan has been adopted indicating that they are scheduled to be drilled
within five years, unless the specific circumstances, justify a longer time.3.
    
    Under no circumstances shall estimates for undeveloped reserves be
attributable to any acreage for which an application of fluid injection or other
improved recovery technique is contemplated, unless such techniques have been proved
effective by actual projects in the same reservoir or an analogous reservoir, as
defined below, or by other evidence using reliable technology establishing
reasonable certainty.Analogous Reservoir
  1.
    
    Same geological formation (but not necessarily in
pressure communication with the reservoir of interest);2.
    
    Same environment of deposition;3.
    
    Similar geological structure; and4.
    
    Same drive mechanism.




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Appendix
Page 3 of 3
 Probable Reserves
  1.
    
    When deterministic methods are used, it is as likely as not that actual
remaining quantities recovered will exceed the sum of estimated proved plus probable
reserves. When probabilistic methods are used, there should be at least a 50%
probability that the actual quantities recovered will equal or exceed the proved
plus probable reserves estimates.2.
    
    Probable reserves may be assigned to areas of a reservoir adjacent to proved
reserves where data control or interpretations of available data are less certain,
even if the interpreted reservoir continuity of structure or productivity does not
meet the reasonable certainty criterion. Probable reserves may be assigned to areas
that are structurally higher than the proved area if these areas are in
communication with the proved reservoir.3.
    
    Probable reserves estimates also include potential incremental quantities
associated with a greater percentage recovery of the hydrocarbons in place than
assumed for proved reserves.4.
    
    See also guidelines in Items 4 and 6 under Possible Reserves.
 Possible Reserves
  1.
    
    When deterministic methods are used, the total quantities ultimately
recovered from a project have a low probability of exceeding proved plus probable
plus possible reserves. When probabilistic methods are used, there should be at
least a 10% probability that the total quantities ultimately recovered will equal or
exceed the proved plus probable plus possible reserves estimates.2.
    
    Possible reserves may be assigned to areas of a reservoir adjacent to
probable reserves where data control and interpretations of available data are
progressively less certain. Frequently, this will be in areas where geoscience and
engineering data are unable to define clearly the area and vertical limits of
commercial production from the reservoir by a defined project.3.
    
    Possible reserves also include incremental quantities associated with a
greater percentage recovery of the hydrocarbons in place than the recovery
quantities assumed for probable reserves.4.
    
    The proved plus probable and proved plus probable plus possible reserves
estimates must be based on reasonable alternative technical and commercial
interpretations within the reservoir or subject project that are clearly documented,
including comparisons to results in successful similar projects.5.
    
    Possible reserves may be assigned where geoscience and engineering data
identify directly adjacent portions of a reservoir within the same accumulation that
may be separated from proved areas by faults with displacement less than formation
thickness or other geological discontinuities and that have not been penetrated by a
wellbore, and the registrant believes that such adjacent portions are in
communication with the known (proved) reservoir. Possible reserves may be assigned
to areas that are structurally higher or lower than the proved area if these areas
are in communication with the proved reservoir.6.
    
    Pursuant to Item 3 under Proved Oil and Gas Reserves, where direct
observation has defined a highest known oil (HKO) elevation and the potential exists
for an associated gas cap, proved oil reserves should be assigned in the
structurally higher portions of the reservoir above the HKO only if the higher
contact can be established with reasonable certainty through reliable technology.
Portions of the reservoir that do not meet this reasonable certainty criterion may
be assigned as probable and possible oil or gas based on reservoir fluid properties
and pressure gradient interpretations.