Exhibit
99








RIDGEWOOD
ENERGY PARTNERSHIPS
 
 
 
 
 
 
 
 
 Estimated
  Future
Reserves and Income
  Attributable
to Certain
  Leasehold
and Royalty Interests
     SEC
Parameters
  (Producing
and Non-Producing Properties)
    As
of
  December
31, 2009
 
 
 
 
 Stephen
      E. Gardner, P.E.
              
              John
      E. Hamlin, P.E.TBPE
      License No. 100578
              
              TBPE
      License No. 65319Senior
      Petroleum Engineer
              
              Managing
      Senior Vice President
 RYDER
SCOTT COMPANY, L.P.
 TBPE Firm
Registration No. F-1580
    RYDER
SCOTT COMPANY   PETROLEUM CONSULTANTS
 TBPE REGISTERED ENGINEERING FIRM
      F-15801100
      LOUISIANA    SUITE 3800
                HOUSTON,
      TEXAS 77002-5218
                FAX
      (713) 651-0849
                  TELEPHONE
      (713) 651-9191
  February
      9, 2010
   Ridgewood
Energy Corporation
 14
Philips Parkway
 Montvale,
NJ  07645-1811
 
 Associates:
 
 At your
request, we have prepared an estimate of the proved, probable and possible
reserves, future production, and income attributable to certain leasehold and
royalty interests of Ridgewood Energy Corporation (Ridgewood) as of December 31,
2009.  Our report entitled “Ridgewood Energy Partnerships” includes
the consolidated interests of all the Ridgewood Partnerships.  The
subject properties are located in the federal waters offshore Louisiana and
Texas and in the state waters offshore Louisiana.At Ridgewood’s request, we
have summarized the producing and non-producing properties separately, where the
non-producing properties comprise those fields that have not yet come on
production.  The reserves and income data were estimated based on the
definitions and disclosure guidelines contained in the United States Securities
and Exchange Commission Title 17, Code of Federal Regulations, Modernization of
Oil and Gas Reporting, Final Rule released January 14, 2009 in the Federal
Register (SEC regulations).  The results of our third party study,
completed on January 18, 2010, are presented herein.  The properties
reviewed by Ryder Scott and included in this report represent 100 percent of the
total net proved, probable and possible reserves on a million cubic foot
equivalent, MMCFE basis, of Ridgewood.
 
 The
estimated reserves and future net income amounts presented in this report, as of
December 31, 2009, are related to hydrocarbon prices.  The hydrocarbon
prices used in the preparation of this report are based on the average prices
during the 12-month period prior to the ending date of the period covered in
this report, determined as unweighted arithmetic averages of the prices in
effect on the first-day-of-the-month for each month within such period, unless
prices were defined by contractual arrangements as required by the SEC
regulations.  Actual future prices may vary significantly from the
prices required by SEC regulations; therefore, volumes of reserves actually
recovered and the amounts of income actually received may differ significantly
from the estimated quantities presented in this report.  The results
of this study are summarized below.
 
 SEC
PARAMETERS
 (Producing
and Non-Producing Properties)
 Estimated
Net Reserves and Income Data
 Certain
Leasehold and Royalty Interests of
 Ridgewood
Energy Partnerships
 As
      of December 31, 2009
  I. PRODUCING
      PROPERTIESProvedDeveloped
                  
                  
                  
                  
                  
                  TotalProducing
                  
                  
                  Non-Producing
                  
                  
                  Undeveloped
                  
                  
                  ProvedNet Remaining ReservesOil/Condensate
      – Barrels
                  
                  
                  269,150
                  
                  
                  
                  637,638
                  
                  
                  
                  18,212
                  
                  
                  
                  925,000Plant
      Products – Barrels
                  
                  
                  42,242
                  
                  
                  
                  7,800
                  
                  
                  
                  0
                  
                  
                  
                  50,042Gas
      – MMCF
                  
                  
                  11,980
                  
                  
                  
                  22,323
                  
                  
                  
                  11,507
                  
                  
                  
                  45,810Income DataFuture
      Gross Revenue
                  
                  $
                  66,956,412
                  
                  
                  $
                  128,066,557
                  
                  
                  $
                  45,983,591
                  
                  
                  $
                  241,006,560Deductions
                  
                  
                  14,713,892
                  
                  
                  
                  32,109,523
                  
                  
                  
                  18,123,693
                  
                  
                  
                  64,947,108Future
      Net Income (FNI)
                  
                  $
                  52,242,520
                  
                  
                  $
                  95,957,034
                  
                  
                  $
                  27,859,898
                  
                  
                  $
                  176,059,452Discounted
      FNI @ 10%
                  
                  $
                  49,409,040
                  
                  
                  $
                  75,313,950
                  
                  
                  $
                  14,679,515
                  
                  
                  $
                  139,402,505
  1200,  530   8TH  AVENUE,
      S.W.
                    CALGARY,
      ALBERTA T2P 3S8
                    TEL
      (403) 262-2799
                    FAX
      (403) 262-2790621  17TH
      STREET, SUITE 1550
                    DENVER,
      COLORADO 80293-1501
                    TEL
      (303) 623-9147
                    FAX
      (303) 623-4258
 
  Ridgewood
Energy Partnerships
 Producing
and Non-Producing Properties
 February
9, 2010
 Page
2
 I. PRODUCING
      PROPERTIES (CONT.)ProbableDeveloped
                  
                  
                  
                  
                  
                  TotalProducing
                  
                  
                  Non-Producing
                  
                  
                  Undeveloped
                  
                  
                  ProbableNet Remaining ReservesOil/Condensate
      – Barrels
                  
                  
                  165,701
                  
                  
                  
                  60,494
                  
                  
                  
                  1,948
                  
                  
                  
                  228,143Plant
      Products – Barrels
                  
                  
                  45,598
                  
                  
                  
                  6,615
                  
                  
                  
                  0
                  
                  
                  
                  55,213Gas
      – MMCF
                  
                  
                  5,671
                  
                  
                  
                  2,473
                  
                  
                  
                  1,929
                  
                  
                  
                  10,073Income DataFuture
      Gross Revenue
                  
                  $
                  34,769,424
                  
                  
                  $
                  14,328,106
                  
                  
                  $
                  7,557,375
                  
                  
                  $
                  56,654,905Deductions
                  
                  
                  3,657,546
                  
                  
                  
                  1,289,601
                  
                  
                  
                  551,033
                  
                  
                  
                  5,498,180Future
      Net Income (FNI)
                  
                  $
                  31,111,878
                  
                  
                  $
                  13,038,505
                  
                  
                  $
                  7,006,342
                  
                  
                  $
                  51,156,725Discounted
      FNI @ 10%
                  
                  $
                  24,004,959
                  
                  
                  $
                  7,320,453
                  
                  
                  $
                  3,320,792
                  
                  
                  $
                  34,646,204
   PossibleDeveloped
                  
                  
                  
                  
                  
                  TotalProducing
                  
                  
                  Non-Producing
                  
                  
                  Undeveloped
                  
                  
                  PossibleNet Remaining ReservesOil/Condensate
      – Barrels
                  
                  
                  44,071
                  
                  
                  
                  76,455
                  
                  
                  
                  4,242
                  
                  
                  
                  124,768Plant
      Products – Barrels
                  
                  
                  23,216
                  
                  
                  
                  0
                  
                  
                  
                  0
                  
                  
                  
                  23,216Gas
      – MMCF
                  
                  
                  2,563
                  
                  
                  
                  1,576
                  
                  
                  
                  2,387
                  
                  
                  
                  6,526Income DataFuture
      Gross Revenue
                  
                  $
                  13,895,432
                  
                  
                  $
                  10,919,607
                  
                  
                  $
                  9,622,182
                  
                  
                  $
                  34,437,221Deductions
                  
                  
                  1,769,638
                  
                  
                  
                  1,630,129
                  
                  
                  
                  636,073
                  
                  
                  
                  4,035,840Future
      Net Income (FNI)
                  
                  $
                  12,125,794
                  
                  
                  $
                  9,289,478
                  
                  
                  $
                  8,986,109
                  
                  
                  $
                  30,401,381Discounted
      FNI @ 10%
                  
                  $
                  7,194,315
                  
                  
                  $
                  7,262,901
                  
                  
                  $
                  4,658,085
                  
                  
                  $
                  19,115,301
 
 
 II.
      NON-PRODUCING PROPERTIESTotal
                  
                  
                  Total
                  
                  
                  TotalProved
                  
                  
                  Probable
                  
                  
                  PossibleUndeveloped
                  
                  
                  Undeveloped
                  
                  
                  UndevelopedNet Remaining ReservesOil/Condensate
      – Barrels
                  
                  
                  1,179,467
                  
                  
                  
                  1,657,075
                  
                  
                  
                  668,499Gas
      – MMCF
                  
                  
                  23,779
                  
                  
                  
                  18,970
                  
                  
                  
                  20,384Income DataFuture
      Gross Revenue
                  
                  $
                  156,725,403
                  
                  
                  $
                  168,854,742
                  
                  
                  $
                  112,800,493Deductions
                  
                  
                  82,940,292
                  
                  
                  
                  23,852,008
                  
                  
                  
                  34,463,028Future
      Net Income (FNI)
                  
                  $
                  73,785,111
                  
                  
                  $
                  145,002,734
                  
                  
                  $
                  78,337,465Discounted
      FNI @ 10%
                  
                  $
                  48,107,475
                  
                  
                  $
                  91,471,113
                  
                  
                  $
                  34,576,644
 RYDER
SCOTT COMPANY   PETROLEUM CONSULTANTS
 Ridgewood
Energy Partnerships
 Producing
and Non-Producing Properties
 February
9, 2010
 Page
3
 III. GRAND
      SUMMARIESProvedDeveloped
                  
                  
                  
                  
                  
                  TotalProducing
                  
                  
                  Non-Producing
                  
                  
                  Undeveloped
                  
                  
                  ProvedNet Remaining ReservesOil/Condensate
      – Barrels
                  
                  
                  269,150
                  
                  
                  
                  637,638
                  
                  
                  
                  1,197,679
                  
                  
                  
                  2,104,467Plant
      Products – Barrels
                  
                  
                  42,242
                  
                  
                  
                  7,800
                  
                  
                  
                  0
                  
                  
                  
                  50,042Gas
      – MMCF
                  
                  
                  11,980
                  
                  
                  
                  22,323
                  
                  
                  
                  35,286
                  
                  
                  
                  69,589Income DataFuture
      Gross Revenue
                  
                  $
                  66,956,412
                  
                  
                  $
                  128,066,557
                  
                  
                  $
                  202,708,994
                  
                  
                  $
                  397,731,963Deductions
                  
                  
                  14,713,892
                  
                  
                  
                  32,109,523
                  
                  
                  
                  101,063,985
                  
                  
                  
                  147,887,400Future
      Net Income (FNI)
                  
                  $
                  52,242,520
                  
                  
                  $
                  95,957,034
                  
                  
                  $
                  101,645,009
                  
                  
                  $
                  249,844,563Discounted
      FNI @ 10%
                  
                  $
                  49,409,040
                  
                  
                  $
                  75,313,950
                  
                  
                  $
                  62,786,990
                  
                  
                  $
                  187,509,980
 
 
 ProbableDeveloped
                  
                  
                  
                  
                  
                  TotalProducing
                  
                  
                  Non-Producing
                  
                  
                  Undeveloped
                  
                  
                  ProbableNet Remaining ReservesOil/Condensate
      – Barrels
                  
                  
                  165,701
                  
                  
                  
                  60,494
                  
                  
                  
                  1,659,023
                  
                  
                  
                  1,885,218Plant
      Products – Barrels
                  
                  
                  48,598
                  
                  
                  
                  6,615
                  
                  
                  
                  0
                  
                  
                  
                  55,213Gas
      – MMCF
                  
                  
                  5,671
                  
                  
                  
                  2,473
                  
                  
                  
                  20,899
                  
                  
                  
                  29,043Income DataFuture
      Gross Revenue
                  
                  $
                  34,769,424
                  
                  
                  $
                  14,328,106
                  
                  
                  $
                  176,412,117
                  
                  
                  $
                  225,509,647Deductions
                  
                  
                  3,657,546
                  
                  
                  
                  1,289,601
                  
                  
                  
                  24,403,041
                  
                  
                  
                  29,350,188Future
      Net Income (FNI)
                  
                  $
                  31,111,878
                  
                  
                  $
                  13,038,505
                  
                  
                  $
                  152,009,076
                  
                  
                  $
                  196,159,459Discounted
      FNI @ 10%
                  
                  $
                  24,004,959
                  
                  
                  $
                  7,320,453
                  
                  
                  $
                  94,791,905
                  
                  
                  $
                  126,117,317
 
 
 PossibleDeveloped
                  
                  
                  
                  
                  
                  TotalProducing
                  
                  
                  Non-Producing
                  
                  
                  Undeveloped
                  
                  
                  PossibleNet Remaining ReservesOil/Condensate
      – Barrels
                  
                  
                  44,071
                  
                  
                  
                  76,455
                  
                  
                  
                  672,741
                  
                  
                  
                  793,267Plant
      Products – Barrels
                  
                  
                  23,216
                  
                  
                  
                  0
                  
                  
                  
                  0
                  
                  
                  
                  23,216Gas
      – MMCF
                  
                  
                  2,563
                  
                  
                  
                  1,576
                  
                  
                  
                  22,771
                  
                  
                  
                  26,910Income DataFuture
      Gross Revenue
                  
                  $
                  13,895,432
                  
                  
                  $
                  10,919,607
                  
                  
                  $
                  122,422,675
                  
                  
                  $
                  147,237,714Deductions
                  
                  
                  1,769,638
                  
                  
                  
                  1,630,129
                  
                  
                  
                  35,099,101
                  
                  
                  
                  38,498,868Future
      Net Income (FNI)
                  
                  $
                  12,125,794
                  
                  
                  $
                  9,289,478
                  
                  
                  $
                  87,323,574
                  
                  
                  $
                  108,738,846Discounted
      FNI @ 10%
                  
                  $
                  7,194,315
                  
                  
                  $
                  7,262,901
                  
                  
                  $
                  39,234,729
                  
                  
                  $
                  53,691,945
 
 Liquid hydrocarbons are expressed in
standard 42 gallon barrels.  All gas volumes are reported on an as
sold basis expressed in millions of cubic feet (MMCF) at the official
temperature and pressure bases of the areas in which the gas reserves are
located.
 RYDER
SCOTT COMPANY   PETROLEUM CONSULTANTS
 Ridgewood
Energy Partnerships
 Producing
and Non-Producing Properties
 February
9, 2010
 Page
4
 The
estimates of the reserves, future production, and income attributable to
properties in this report were prepared using the economic software package
PHDWin Petroleum Economic Evaluation Software, a copyrighted program of TRC
Consultants L.C.  The program was used solely at the request of
Ridgewood.  Ryder Scott has found this program to be generally
acceptable, but notes that certain summaries and calculations may vary due to
rounding and may not exactly match the sum of the properties being
summarized.  Furthermore, one line economic summaries may vary
slightly from the more detailed cash flow projections of the same properties,
also due to rounding.  The rounding differences are not
material.
 
 The
future gross revenue is after the deduction of production taxes.  The
deductions comprise the normal direct costs of operating the wells, ad valorem
taxes, recompletion costs, development costs, and certain abandonment costs net
of salvage.  Certain gas, oil and condensate processing and handling
fees, including compression fees where applicable, are included as “other”
costs.  The future net income is before the deduction of state and
federal income taxes and general administrative overhead, and has not been
adjusted for outstanding loans that may exist nor does it include any adjustment
for cash on hand or undistributed income.
 
 At the
grand summary level, gas reserves account for approximately 69 percent of the
total future gross revenue from proved reserves and liquid hydrocarbon reserves
account for the remaining 31 percent of total future gross revenue from proved
reserves.  Similarly, gas reserves account for approximately 51
percent of the total future gross revenue from probable reserves and liquid
hydrocarbon reserves account for the remaining 49 percent of total future gross
revenue from probable reserves.  Gas reserves account for
approximately 69 percent of the total future gross revenue from possible
reserves and liquid hydrocarbon reserves account for the remaining 31 percent of
total future gross revenue from possible reserves.
 
 The
discounted future net income shown above was calculated using a discount rate of
10 percent per annum compounded monthly.  Future net income was
discounted at five other discount rates, which were also compounded
monthly.  These results are shown in summary form as
follows.
 
 I.  PRODUCING
      PROPERTIESDiscounted
      Future Net IncomeAs
      of December 31, 2009Discount
      Rate
                  
                  Total
                  
                  Total
                  
                  TotalPercent
                  
                  Proved
                  
                  Probable
                  
                  Possible8
                  
                  $145,613,650
                  
                  $37,196,987
                  
                  $20,810,86312
                  
                  $133,651,548
                  
                  $32,370,094
                  
                  $17,621,60015
                  
                  $125,797,235
                  
                  $29,391,475
                  
                  $15,697,77320
                  
                  $114,468,155
                  
                  $25,350,898
                  
                  $13,152,41530
                  
                  $  96,848,976
                  
                  $19,634,904
                  
                  $   9,702,984
 
 II.  NON-PRODUCING
      PROPERTIESDiscounted
      Future Net IncomeAs
      of December 31, 2009Discount
      Rate
                  
                  Total
                  
                  Total
                  
                  TotalPercent
                  
                  Proved
                  
                  Probable
                  
                  Possible8
                  
                  $52,279,983
                  
                  $99,191,299
                  
                  $39,851,92012
                  
                  $44,312,298
                  
                  $84,765,804
                  
                  $30,274,89215
                  
                  $39,238,366
                  
                  $76,257,126
                  
                  $25,173,97420
                  
                  $22,152,687
                  
                  $65,196,134
                  
                  $19,076,91930
                  
                  $21,730,142
                  
                  $50,415,829
                  
                  $11,591,792
 RYDER
SCOTT COMPANY   PETROLEUM CONSULTANTS
 Ridgewood
Energy Partnerships
 Producing
and Non-Producing Properties
 February
9, 2010
 Page
5
 III.  GRAND
      SUMMARIESDiscounted
      Future Net IncomeAs
      of December 31, 2009Discount
      Rate
                  
                  Total
                  
                  Total
                  
                  TotalPercent
                  
                  Proved
                  
                  Probable
                  
                  Possible8
                  
                  $197,893,633
                  
                  $136,388,286
                  
                  $60,662,78312
                  
                  $177,963,846
                  
                  $117,135,898
                  
                  $47,896,49215
                  
                  $165,035,601
                  
                  $105,648,601
                  
                  $40,871,74720
                  
                  $146,620,842
                  
                  $  90,547,032
                  
                  $32,229,33430
                  
                  $118,579,118
                  
                  $  70,050,733
                  
                  $21,294,776
 
 The
results shown above are presented for your information and should not be
construed as our estimate of fair market value.
 
 Reserves
Included in This Report
 
 The
proved, probable and possible reserves included herein conform to the
definitions as set forth in the Securities and Exchange Commission’s Regulations
Part 210.4-10 (a).  An abridged version of the SEC reserves
definitions from 210.4-10(a) entitled “Petroleum Reserves Definitions” is
included as an attachment to this report.
 
 The
various reserve status categories are defined in the attachment to this report
entitled “Petroleum Reserves Definitions.”  The developed proved
non-producing reserves included herein are associated with the producing
properties, and consist of the shut-in and behind pipe
categories.  The developed probable and possible non-producing
reserves included herein are also associated with the producing properties and
consist of the behind pipe category.
 
 No
attempt was made to quantify or otherwise account for any accumulated gas
production imbalances that may exist.  The gas volumes included herein
do not attribute gas consumed in operations as reserves.
 
 While it
may reasonably be anticipated that the future prices received for the sale of
production and the operating costs and other costs relating to such production
may also increase or decrease from existing levels, such changes were, in
accordance with rules adopted by the SEC, omitted from consideration in making
this evaluation.
 
 Proved
oil and gas reserves are those quantities of oil and gas, which, by analysis of
geoscience and engineering data, can be estimated with reasonable certainty to
be economically producible from a given date forward.  Probable
reserves are those additional reserves that are less certain to be recovered
than proved reserves but which, together with proved reserves, are as likely as
not to be recovered.  Possible reserves are those additional reserves
which are less certain to be recovered than probable reserves and thus the
probability of achieving or exceeding the proved plus probable plus possible
reserves is low.  The reserves included herein were estimated using
deterministic methods and presented as incremental quantities.  Under
the deterministic approach, discrete quantities of reserves are estimated and
assigned separately as proved, probable and possible based on their individual
levels of uncertainty.
 
 The
reserves and income quantitiesattributable
to the different reserve classifications that are included herein have not been
adjusted to reflect these varying degrees of risk associated with them and thus
are not comparable.  Moreover, estimates of reserves may increase or
decrease as a result of future operations, effects of regulation by governmental
agencies or geopolitical risks.  As a result, the estimates of oil and
gas reserves have an intrinsic uncertainty.  The reserves included in
this report are therefore estimates only and should not be construed as being
exact quantities.  They may or may not be actually recovered, and if
recovered, the revenues therefrom and the actual
costs related theretocould be more or less than the estimated
amounts.
 RYDER
SCOTT COMPANY   PETROLEUM CONSULTANTS
 Ridgewood
Energy Partnerships
 Producing
and Non-Producing Properties
 February
9, 2010
 Page
6
 Ridgewood’s
operations may be subject to various levels of governmental controls and
regulations.  These controls and regulations may include matters
relating to land tenure, drilling, production practices, environmental
protection, marketing and pricing policies, royalties, and various taxes and
levies including income tax, and are subject to change from time to
time.  Such changes in governmental regulations and policies may cause
volumes of reserves actually recovered and amounts of income actually received
to differ significantly from the estimated quantities.
 
 The
estimates of reserves presented herein were based upon a detailed study of the
properties in which Ridgewood owns an interest; however, we have not made any
field examination of the properties.  No consideration was given in
this report to potential environmental liabilities that may exist nor were any
costs included for potential liability to restore and clean up damages, if any,
caused by past operating practices.
 
 Estimates
of Reserves
 
 The
reserves for the properties included herein were estimated by performance
methods or the volumetric method.  In general, reserves attributable
to producing wells and/or reservoirs were estimated by performance methods such
as decline curve analysis and/or material balance, which utilized extrapolations
of historical production and pressure data available through November, 2009 in
those cases where such data were considered to be definitive.  In
certain cases, producing reserves were estimated by the volumetric method where
there were inadequate historical performance data to establish a definitive
trend and where the use of production performance data as a basis for the
reserve estimates was considered to be inappropriate.  Reserves
attributable to proved, probable and possible non-producing and undeveloped
reserves included herein were primarily estimated by the volumetric method,
which utilized all pertinent well and seismic data available through November,
2009 for the producing properties and through December, 2009 for the
non-producing properties.  We utilized all methods and procedures that
we deemed necessary to estimate Ridgewood’s proved, probable and possible
reserves, and we affirm that those methods were appropriate for this
purpose.
 
 To
estimate economically recoverable oil and gas reserves and related future net cash flows, we consider
many factors and assumptions including, but not limited to, the use of reservoir
parameters derived from geological, geophysical and engineering data that cannot
be measured directly, economic criteria based on current costs and SEC pricing
requirements, and forecasts of future production rates.  Under the SEC regulations 210.4-10(a)(22)(v) and (26),
proved, probable and possible reserves must be demonstrated to be economically
producible based on existing economic conditions including the prices and costs
at which economic producibility from a reservoir is to be determined as of the
effective date of the report.  Ridgewood has informed us that they
have furnished us all of the accounts, records, geological and engineering data,
and reports and other data required for this investigation.In
preparing our forecast of future production and income, we have relied upon data
furnished by Ridgewood with respect to property interests owned, production and
well tests from examined wells, normal direct costs of operating the wells or
leases, other costs such as transportation and/or processing fees, recompletion
and development costs, abandonment costs after salvage, product prices based on
the SEC regulations, geological structural and isochore maps, well logs, core
analyses, and pressure measurements.  Ryder Scott reviewed such
factual data for its reasonableness; however, we have not conducted an
independent verification of the data supplied by Ridgewood.
 
 Future
Production Rates
 
 Our
forecasts of future production rates are based on historical performance from
wells now on production.  Test data and other related information were
used to estimate the anticipated initial production rates for those wells or
locations that are not currently producing.  If no production decline
trend has been established, future production rates were held constant, or
adjusted for the effects of curtailment where appropriate, until a decline in
ability to produce was anticipated.  An estimated rate of decline was
then applied to depletion of the reserves.  If a decline trend has
been established, this trend was used as the basis for estimating future
production rates.  For reserves not yet on production, sales were
estimated to commence at an anticipated date furnished by
Ridgewood.
 RYDER
SCOTT COMPANY   PETROLEUM CONSULTANTS
 Ridgewood
Energy Partnerships
 Producing
and Non-Producing Properties
 February
9, 2010
 Page
7
 The
future production rates from wells now on production may be more or less than
estimated because of changes in market demand or allowables set by regulatory
bodies.  Wells or locations that are not currently producing may start
producing earlier or later than anticipated in our estimates.
 
 Hydrocarbon
Prices
 
 As previously stated, the hydrocarbon prices used herein
are based on theaverage prices during the 12-month period prior to the
ending date of the period covered in this report, determined as the unweighted
arithmetic averages of the prices in effect on the first-day-of-the-month for
each month within such period.  Product prices that were actually used
for each property reflect adjustment for gravity, quality, local conditions,
and/or distance from market.
 
 The
effects of derivative instruments designated as price hedges of oil and gas
quantities are not reflected in our individual property
evaluations.
 
 Costs
 
 Operating
costs for the leases and wells in this report are based on the operating expense
reports of Ridgewood and include only those costs directly applicable to the
leases or wells. The operating costs include a portion of general and
administrative costs allocated directly to the leases and wells.  When
applicable for operated properties, the operating costs include an appropriate
level of corporate general administrative and overhead costs.  The
operating costs for non-operated properties include the COPAS overhead costs
that are allocated directly to the leases and wells under terms of operating
agreements.  Certain gas, oil and condensate processing and handling
fees, including compression fees where applicable, are included as “other”
costs.  No deduction was made for loan repayments, interest expenses,
or exploration and development prepayments that were not charged directly to the
leases or wells.
 
 Development
costs were furnished to us by Ridgewood and are based on authorizations for
expenditure for the proposed work or actual costs for similar
projects.  The estimated net cost of abandonment after salvage was
included for properties where abandonment costs net of salvage was
significant.  The estimates of the net abandonment costs furnished by
Ridgewood were accepted without independent verification.
 
 Because
of the direct relationship between volumes of proved, probable and possible
undeveloped reserves and development plans, we include in the proved, probable
and possible undeveloped category only reserves assigned to undeveloped
locations that we have been assured will definitely be
drilled.  Ridgewoodhas assured us of
their intent and ability to proceed with the development activities included in
this report, and that they are not aware of any legal, regulatory or political
obstacles that would significantly alter their plans.
 
 Current
costs used by Ridgewood were held constant throughout the life of the
properties.
 
 Standards
of Independence and Professional Qualification
 
 Ryder
Scott is an independent petroleum engineering consulting firm that has been
providing petroleum consulting services throughout the world for over seventy
years.  Ryder Scott is employee owned and maintains offices in
Houston, Texas; Denver, Colorado; and Calgary, Alberta, Canada.  We
have over eighty engineers and geoscientists on our permanent
staff.  By virtue of the size of our firm and the large number of
clients for which we provide services, no single client or job represents a
material portion of our annual revenue.  We do not serve as officers
or directors of any publicly traded oil and gas company and are separate and
independent from the operating and investment decision-making process of our
clients.  This allows us to bring the highest level of independence
and objectivity to each engagement for our services.
 RYDER
SCOTT COMPANY   PETROLEUM CONSULTANTS
 Ridgewood
Energy Partnerships
 Producing
and Non-Producing Properties
 February
9, 2010
 Page
8
 Ryder
Scott actively participates in industry related professional societies and
organizes an annual public forum focused on the subject of reserves evaluations
and SEC regulations.  Many of our staff have authored or co-authored
technical papers on the subject of reserves related topics.  We
encourage our staff to maintain and enhance their professional skills by
actively participating in ongoing continuing education.
 
 Ryder
Scott requires that staff engineers and geoscientists have received professional
accreditation, and are maintaining in good standing, a registered or certified
professional engineer’s license or a registered or certified professional
geoscientist’s license, or the equivalent thereof, from an appropriate
governmental authority or a recognized self-regulating professional organization
prior to becoming an officer of the Company.
 
 We are
independent petroleum engineers with respect to Ridgewood.  Neither we
nor any of any of our employees have any interest in the subject properties, and
neither the employment to do this work nor the compensation is contingent on our
estimates of reserves for the properties that were reviewed.
 
 The
professional qualifications of the undersigned, the technical persons primarily
responsible for reviewing and approving the reserves information discussed in
this report are included as an attachment to this letter.
 
 Terms
of Usage
 
 This
report was prepared for the exclusive use and sole benefit of Ridgewood Energy
Corporation and may not be put to other use without our prior written consent
for such use.  The data and work papers used in the preparation of
this report are available for examination by authorized parties in our
offices.  Please contact us if we can be of further
service.
  Very
      truly yours,RYDER
      SCOTT COMPANY, L.P.TBPE
      Firm Registration No. F-1580Stephen
      E. Gardner, P.E.TBPE
      License No. 100578Senior
      Petroleum EngineerJohn
      E. Hamlin, P.E.TBPE
      License No. 65319Managing
      Senior Vice President
 
 SEG-JEH/sm
   RYDER
SCOTT COMPANY   PETROLEUM CONSULTANTS
 Professional
Qualifications of Primary Technical Person
 
 The
conclusions presented in this report are the result of technical analysis
conducted by teams of geoscientists and engineers from Ryder Scott Company,
L.P.  Mr. John E. Hamlin was the primary technical person responsible
for overseeing the estimate of the reserves, future production, and income
presented herein.
 
 Mr.
Hamlin, an employee of Ryder Scott Company L.P. (Ryder Scott) since 1979, is a
Managing Senior Vice President and also serves as an Engineering Group
Supervisor responsible for coordinating and supervising staff and consulting
engineers of the company in ongoing reservoir evaluation studies
worldwide.  Before joining Ryder Scott, Mr. Hamlin served in a number
of engineering positions with Phillips Petroleum Corporation.  For
more information regarding Mr. Hamlin’s geographic and job specific experience,
please refer to the Ryder Scott Company website at
 http://www.ryderscott.com/Experience/Employees.php.
 
 Mr.
Hamlin earned a Bachelor of Science degree in Petroleum Engineering from the
University of Texas at Austin in 1975 and is a registered Professional Engineer
in the State of Texas.  He is also a member of the Society of
Petroleum Engineers.
 
 In
addition to gaining experience and competency through prior work experience, the
Texas Board of Professional Engineers requires a minimum of 15 hours of
continuing education annually, including at least one hour in the area of
professional ethics, which Mr. Hamlin fulfills.  As part of his 2009
continuing education hours, Mr. Hamlin attended an internally presented 9hours of formalized
training as well as a day long public forum relating to the definitions and
disclosure guidelines contained in the United States Securities and Exchange
Commission Title 17, Code of Federal Regulations, Modernization of Oil and Gas
Reporting, Final Rule released January 14, 2009 in the Federal
Register.  Mr. Hamlin attended an additional 24 hours of formalized
in-house training as well as an additional 4 hours of formalized external
training during 2009 covering such topics as the SPE/WPC/AAPG/SPEE Petroleum
Resources Management System, reservoir engineering, geoscience and petroleum
economics evaluation methods, procedures and software and ethics for
consultants.
 
 Based on
his educational background, professional training and more than 33 years of
practical experience in the estimation and evaluation of petroleum reserves, Mr.
Hamlin has attained the professional qualifications as a Reserves Estimator and
Reserves Auditor set forth in Article III of the “Standards Pertaining to the
Estimating and Auditing of Oil and Gas Reserves Information” promulgated by the
Society of Petroleum Engineers as of February 19, 2007.
 RYDER
SCOTT COMPANY   PETROLEUM CONSULTANTS


PETROLEUM
RESERVES DEFINITIONS
 
 As
Adapted From:
 RULE
4-10(a) of REGULATION S-X PART 210
 UNITED
STATES SECURITIES AND EXCHANGE COMMISSION (SEC)
 
  PREAMBLE
 
 On January 14, 2009, the United States
Securities and Exchange Commission (“the Commission”) published the
“Modernization of Oil and Gas Reporting; Final Rule” in the Federal Register of
National Archives and Records Administration (NARA).  The
“Modernization of Oil and Gas Reporting; Final Rule” includes revisions and
additions to the definition section in Rule 4-10 of Regulation S-X, revisions
and additions to the oil and gas reporting requirements in Regulation S-K, and
amends and codifies Industry Guide 2 in Regulation S-K.  The
“Modernization of Oil and Gas Reporting; Final Rule”, including all references
to Regulation S-X and Regulation S-K, shall be referred to herein collectively
as the “SEC Regulations”.  The SEC Regulations take effect with all
filings made with the United States Securities and Exchange Commission as of
December 31, 2009, or after January 1, 2010.  Reference should be made
to the full text under Title 17, Code of Federal Regulations, Regulation S-X
Part 210, Rule 4-10 (a) for the complete definitions, as the following
definitions, descriptions and explanations rely wholly or in part on excerpts
from the original document (direct passages excerpted from the aforementioned
SEC document are denoted in italics herein).
 
 Reserves are those quantities of
petroleum which are anticipated to be commercially recovered from known
accumulations from a given date forward under defined conditions.  All
reserve estimates involve some degree of uncertainty.  The uncertainty
depends chiefly on the amount of reliable geologic and engineering data
available at the time of the estimate and the interpretation of these
data.  The relative degree of uncertainty may be conveyed by placing
reserves into one of two principal classifications, either proved or
unproved.  Unproved reserves are less certain to be recovered than
proved reserves and may be further sub-classified as probable and possible
reserves to denote progressively increasing uncertainty in their
recoverability.  Under the SEC Regulations as of December 31,
2009, or after January 1, 2010, a company may optionally disclose estimated
quantities of probable or possible oil and gas reserves in documents publicly
filed with the Commission.  The SEC Regulations continue to prohibit
disclosure of estimates of oil and gas resources other than reserves and any
estimated values of such resources in any document publicly filed with the
Commission unless such information is required to be disclosed in the document
by foreign or state law as noted in §229.102 (5).
 
 Reserves estimates will generally be
revised as additional geologic or engineering data become available or as
economic conditions change.
 
 Reserves may be attributed
to either natural energy or improved recovery methods.  Improved
recovery methods include all methods for supplementing natural energy or
altering natural forces in the reservoir to increase ultimate
recovery.  Examples of such methods are pressure maintenance, cycling,
waterflooding, thermal methods, chemical flooding, and the use of miscible and
immiscible displacement fluids.  Other improved recovery methods may
be developed in the future as petroleum technology continues to
evolve.
  RYDER
SCOTT COMPANY   PETROLEUM CONSULTANTS
 PETROLEUM
RESERVES DEFINITIONS
 Page
2
 RESERVES (SEC
DEFINITIONS)
 
 Securities and Exchange Commission
Regulation S-X §229.4-10(a) (26) defines reserves as follows:
 
 Reserves.Reserves
are estimated remaining quantities of oil and gas and related substances
anticipated to be economically producible, as of a given date, by application of
development projects to known accumulations.  In addition, there must
exist, or there must be a reasonable expectation that there will exist, the
legal right to produce or a revenue interest in the production, installed means
of delivering oil and gas or related substances to market, and all permits and
financing required to implement the project.
 
 Note to paragraph
(a)(26): Reserves should not be assigned to adjacent reservoirs isolated
by major, potentially sealing, faults until those reservoirs are penetrated and
evaluated as economically producible.  Reserves should not be assigned
to areas that are clearly separated from a known accumulation by a
non-productive reservoir (i.e., absence of
reservoir, structurally low reservoir, or negative test
results).  Such areas may contain prospective resources (i.e., potentially
recoverable resources from undiscovered accumulations).
 
 
 PROVED RESERVES (SEC
DEFINITIONS)
 
 Securities and Exchange Commission
Regulation S-X §229.4-10(a) (22) defines proved oil and gas reserves as
follows:
 
 Proved oil and gas
reserves.Proved oil and gas reserves are those quantities of
oil and gas, which, by analysis of geoscience and engineering data, can be
estimated with reasonable certainty to be economically producible—from a given
date forward, from known reservoirs, and under existing economic conditions,
operating methods, and government regulations—prior to the time at which
contracts providing the right to operate expire, unless evidence indicates that
renewal is reasonably certain, regardless of whether deterministic or
probabilistic methods are used for the estimation. The project to extract the
hydrocarbons must have commenced or the operator must be reasonably certain that
it will commence the project within a reasonable time.
 
 (i)
The area of the reservoir considered as proved includes:
 
 (A)
The area identified by drilling and limited by fluid contacts, if any,
and
 
 (B)
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.
 
 (ii)
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.
 
 (iii)
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.
 RYDER
SCOTT COMPANY   PETROLEUM CONSULTANTS
 PETROLEUM
RESERVES DEFINITIONS
 Page
3
 (iv)
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; and
 
 (B)
The project has been approved for development by all necessary parties and
entities, including governmental entities.
 
 (v)
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.
 
 
 PROBABLE RESERVES (SEC
DEFINITIONS)
 
 Securities and Exchange Commission
Regulation S-X §229.4-10(a) (18) defines probable oil and gas reserves as
follows:
 
 Probable
reserves.Probable reserves are those additional reserves that
are less certain to be recovered than proved reserves but which, together with
proved reserves, are as likely as not to be recovered.
 
 (i)
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.
 
 (ii)
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.
 
 (iii)
Probable reserves estimates also include potential incremental quantities
associated with a greater percentage recovery of the hydrocarbons in place than
assumed for proved reserves.
 
 (iv)
See also guidelines in paragraphs (a)(17)(iv) and (a)(17)(vi) of this
section.
 
 
 POSSIBLE RESERVES (SEC
DEFINITIONS)
 
 Securities and Exchange Commission
Regulation S-X §229.4-10(a) (17) defines possible oil and gas reserves as
follows:
 RYDER
SCOTT COMPANY   PETROLEUM CONSULTANTS
 PETROLEUM
RESERVES DEFINITIONS
 Page
4
 Possible
reserves.Possible reserves are those additional reserves that
are less certain to be recovered than probable reserves.
 
 (i)
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.
 
 (ii)
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.
 
 (iii)
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.
 
 (iv)
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.
 
 (v)
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.
 
 (vi)
Pursuant to paragraph (a)(22)(iii) of this section, 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.
 
 
 
 
 [Remainder
of this page is left blank intentionally]
 RYDER
SCOTT COMPANY   PETROLEUM CONSULTANTS
 RESERVES
STATUS DEFINITIONS AND GUIDELINES
 
 As
Adapted From:
 RULE
4-10(a) of REGULATION S-X PART 210
 UNITED
STATES SECURITIES AND EXCHANGE COMMISSION (SEC)
 
 and
  PETROLEUM
RESOURCES MANAGEMENT SYSTEM (SPE-PRMS)
 Sponsored
and Approved by:
 SOCIETY
OF PETROLEUM ENGINEERS (SPE),
 WORLD
PETROLEUM COUNCIL (WPC)
 AMERICAN
ASSOCIATION OF PETROLEUM GEOLOGISTS (AAPG)
 SOCIETY
OF PETROLEUM EVALUATION ENGINEERS (SPEE)
    Reserves status categories define the
development and producing status of wells and reservoirs.
 
 
 DEVELOPED RESERVES (SEC
DEFINITIONS)
 
 Securities and Exchange Commission
Regulation S-X §229.4-10(a) (6) defines developed oil and gas reserves as
follows:
 
 Developed
oil and gas reserves are reserves of any category that can be expected to be
recovered:
 
 (i)
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; and
 
 (ii)
Through installed extraction equipment and infrastructure operational at the
time of the reserves estimate if the extraction is by means not involving a
well.
 
 Developed Producing
(SPE-PRMS Definitions)
 While not a requirement for disclosure
under the SEC regulations, developed oil and gas reserves may be further
sub-classified according to the guidance contained in the SPE-PRMS as Producing
or Non-Producing.
 
 Developed
Producing Reserves
 Developed
Producing Reserves are expected to be recovered from completion intervals that
are open and producing at the time of the estimate.
 
 Improved
recovery reserves are considered producing only after the improved recovery
project is in operation.
 
 Developed
Non-Producing
 Developed
Non-Producing Reserves include shut-in and behind-pipe reserves.
 RYDER
SCOTT COMPANY   PETROLEUM CONSULTANTS
 RESERVES
STATUS DEFINITIONS AND
GUIDELINES
 Page
2
   Shut-In
 Shut-in
Reserves are expected to be recovered from:
 (1)
              completion
      intervals which are open at the time of the estimate but which have not
      yet started producing;
 (2)
              wells
      which were shut-in for market conditions or pipeline connections;
      or
 (3)
              wells
      not capable of production for mechanical
  reasons.
 
 Behind-Pipe
 Behind-pipe
Reserves are expected to be recovered from zones in existing wells which will
require additional completion work or future re-completion prior to start of
production.
 
 In
all cases, production can be initiated or restored with relatively low
expenditure compared to the cost of drilling a new well.
 
 
 UNDEVELOPED RESERVES (SEC
DEFINITIONS)
 
 Securities and Exchange Commission
Regulation S-X §229.4-10(a) (31) defines undeveloped oil and gas reserves as
follows:
 
 Undeveloped
oil and gas reserves are reserves of any category that are expected to be
recovered from new wells on undrilled acreage, or from existing wells where a
relatively major expenditure is required for recompletion.
 
 (i)  
 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.
 
 (ii)
 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.
 
 (iii)
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 in paragraph (a)(2) of this section, or by other evidence using reliable
technology establishing reasonable certainty.
    RYDER
SCOTT COMPANY   PETROLEUM CONSULTANTS