UNITED
STATES


SECURITIES AND EXCHANGE
COMMISSION





Washington,
D.C. 20549





FORM 10-Q





x
            QUARTERLY
      REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF
      1934For
      the quarterly period ended June 30, 2008oro
            TRANSITION
      REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF
      1934For
      the transition period from
      _______________________to____________________________




Commission
File Number 000-51268





RIDGEWOOD
ENERGY M FUND, LLC


(Exact
name of registrant as specified in its charter)




Delaware
                (State
      or other jurisdiction of
                incorporation
      or organization)
              
              13-4285167
                (I.R.S.
      Employer
                Identification
      No.)


1314
King Street, Wilmington, Delaware 19801


(Address
of principal executive offices) (Zip code)





(302)
888-7444


(Registrant’s
telephone number, including area code)





Securities
registered pursuant to Section 12(b) of the Act: None


Securities
registered pursuant to Section 12(g) of the Act:





Shares of
LLC Membership Interest





Indicate
by check mark whether the registrant (1) has filed all reports required to
be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934
during the preceding 12 months (or for such shorter period that the
registrant was required to file such reports), and (2) has been subject to
such filing requirements for the past 90 days.


Yes  xNo  o





Indicate
by check mark whether the registrant is a large accelerated filer, an
accelerated filer, a non-accelerated filer, or a smaller reporting company. See
definitions of “large accelerated filer,” “accelerated filer,” and “smaller
reporting company” in Rule 12b-2 of the Exchange Act. (Check
one):


Large
      accelerated filer
                  o
                  Accelerated
      filer
                  oNon-accelerated
      filer
                      (Do
      not check if a smaller reporting company)
                  o
                  Smaller
      reporting company
                  x


Indicate
by check mark whether the registrant is a shell company (as defined in Rule
12b-2 of the Act).  Yes o  No x





There is
no market for the shares. As of August 6, 2008 there are 535.6818 shares
outstanding.











Table
      of ContentsPart I - FINANCIAL INFORMATION
              
              PageItem 1.     Financial
      Statements:
              
              3Unaudited Condensed Balance Sheets as of June 30, 2008 and
      December 31, 2007
              
              3Unaudited Condensed Statements of Operations for the three
      and six months ended
                June 30, 2008 and 2007
              
              4Unaudited Condensed Statements of Cash Flows for six months
      ended
                June 30, 2008 and 2007
              
              5Notes to Unaudited Condensed Financial
      Statements
              
              6Item 2.    Management's Discussion and Analysis of Financial Condition
      and Results of Operations
              
              12Item 3.     Quantitative and Qualitative Disclosures about Market
      Risk
              
              17Item 4.     Controls
      and Procedures
              
              17Part II - OTHER INFORMATIONItem 1.     Legal Proceedings
              
              18Item 1A. Risk
      Factors
              
              18Item 2.     Unregistered Sales of Equity Securities and Use of
      Proceeds
              
              18Item 3.    Defaults Upon Senior Securities
              
              18Item 4.   Submissions of Matters to a Vote of Security
      Holders
              
              18Item 5.   Other Information
              
              18Item 6.   Exhibits
              
              18SIGNATURES
              
              19


2






Part I- Financial InformationItem
      1.  Financial StatementsRIDGEWOOD
      ENERGY M FUND, LLCUNAUDITED
      CONDENSED BALANCE SHEETS(in
      thousands, except share amounts)June
      30, 2008
              
              
              December
      31, 2007ASSETSCurrent
      assets:Cash
      and cash equivalents
              
              $
              7,833
              
              
              $
              8,163Short-term
      investment in marketable securities
              
              
              -
              
              
              
              5,075Production
      receivable
              
              
              116
              
              
              
              119Other
      current assets
              
              
              119
              
              
              
              99Total
      current assets
              
              
              8,068
              
              
              
              13,456Salvage
      fund
              
              
              1,126
              
              
              
              1,111Oil
      and gas properties:Advances
      to operators for working interests and expenditures
              
              
              -
              
              
              
              66Unproved
      properties
              
              
              3,694
              
              
              
              7,357Proved
      properties
              
              
              22,580
              
              
              
              15,033Less:
      accumulated depletion and amortization
              
              
              (8,227
              )
              
              
              (7,909
              )Total
      oil and gas properties, net
              
              
              18,047
              
              
              
              14,547Total
      assets
              
              $
              27,241
              
              
              $
              29,114LIABILITIES
      AND MEMBERS' CAPITALCurrent
      liabilities:Due
      to operators
              
              $
              1,373
              
              
              $
              1,367Accrued
      expenses payable
              
              
              70
              
              
              
              137Total
      current liabilities
              
              
              1,443
              
              
              
              1,504Asset
      retirement obligations
              
              
              681
              
              
              
              476Total
      liabilities
              
              
              2,124
              
              
              
              1,980Commitments
      and contingencies (Note 8)Members'
      capital:Manager:Distributions
              
              
              (1,402
              )
              
              
              (1,402
              )Accumulated
      (deficit) earnings
              
              
              (5
              )
              
              
              97Manager's
      total
              
              
              (1,407
              )
              
              
              (1,305
              )Shareholders:Capital
      contributions (834 shares authorized;  535.6818 issued
      and
                outstanding)
              
              
              78,887
              
              
              
              78,887Syndication
      costs
              
              
              (8,597
              )
              
              
              (8,597
              )Distributions
              
              
              (7,945
              )
              
              
              (7,945
              )Accumulated
      deficit
              
              
              (35,821
              )
              
              
              (33,906
              )Shareholders'
      total
              
              
              26,524
              
              
              
              28,439Total
      members' capital
              
              
              25,117
              
              
              
              27,134Total
      liabilities and members' capital
              
              $
              27,241
              
              
              $
              29,114The
      accompanying notes are an integral part of these unaudited condensed
      financial statements.
 
 3


RIDGEWOOD
      ENERGY M FUND, LLCUNAUDITED CONDENSED STATEMENTS OF
  OPERATIONS(in
      thousands, except share
amounts)
  Three
      months ended June 30,
              
              
              Six
      months ended June 30,2008
              
              
              2007
              
              
              2008
              
              
              2007RevenueOil
      and gas revenue
              
              $
              182
              
              
              $
              1,175
              
              
              $
              628
              
              
              $
              2,553ExpensesDepletion
      and amortization
              
              
              82
              
              
              
              386
              
              
              
              318
              
              
              
              775Dry-hole
      costs
              
              
              1,256
              
              
              
              (46
              )
              
              
              1,703
              
              
              
              (46
              )Management
      fees to affiliate (Note 6)
              
              
              -
              
              
              
              322
              
              
              
              -
              
              
              
              645Impairment
      of proved property
              
              
              -
              
              
              
              -
              
              
              
              (471
              )
              
              
              -Operating
      expenses
              
              
              38
              
              
              
              235
              
              
              
              957
              
              
              
              628General
      and administrative expenses
              
              
              123
              
              
              
              132
              
              
              
              274
              
              
              
              314Total
      expenses
              
              
              1,499
              
              
              
              1,029
              
              
              
              2,781
              
              
              
              2,316(Loss)
      income from operations
              
              
              (1,317
              )
              
              
              146
              
              
              
              (2,153
              )
              
              
              237Other
      incomeInterest
      income
              
              
              48
              
              
              
              256
              
              
              
              136
              
              
              
              535Net
      (loss) income
              
              $
              (1,269
              )
              
              $
              402
              
              
              $
              (2,017
              )
              
              $
              772Manager
      InterestNet
      (loss) income
              
              $
              (9
              )
              
              $
              76
              
              
              $
              (102
              )
              
              $
              149Shareholder
      InterestNet
      (loss) income
              
              $
              (1,260
              )
              
              $
              326
              
              
              $
              (1,915
              )
              
              $
              623Net
      (loss) income per share
              
              $
              (2,352
              )
              
              $
              609
              
              
              $
              (3,575
              )
              
              $
              1,163The
      accompanying notes are an integral part of these unaudited condensed
      financial statements.
  4
 RIDGEWOOD ENERGY M FUND, LLCUNAUDITED CONDENSED STATEMENTS OF CASH FLOWS(in
      thousands)Six
      months ended June 30,2008
                
                
                2007Cash
      flows from operating activitiesNet
      (loss) income
                
                $
                (2,017
                )
                
                $
                772Adjustments
      to reconcile net (loss) income to net cash provided by
                  operating
      activities:Depletion
      and amortization
                
                
                318
                
                
                
                775Dry-hole
      costs
                
                
                1,703
                
                
                
                (46
                )Settlement
      of asset retirement obligation
                
                
                (28
                )
                
                
                -Accretion
      expense
                
                
                6
                
                
                
                6Interest
      earned on marketable securities
                
                
                (36
                )
                
                
                (260
                )Changes
      in assets and liabilities:Decrease
      in production receivable
                
                
                3
                
                
                
                61Decrease
      (increase) in other current assets
                
                
                77
                
                
                
                (51
                )Increase
      (decrease) in due to operators
                
                
                193
                
                
                
                (88
                )Decrease
      in accrued expenses payable
                
                
                (67
                )
                
                
                (53
                )Net
      cash provided by operating activities
                
                
                152
                
                
                
                1,116Cash
      flows from investing activitiesCapital
      expenditures for oil and gas properties
                
                
                (5,578
                )
                
                
                (3,648
                )Interest
      reinvested in salvage fund
                
                
                (15
                )
                
                
                (17
                )Proceeds
      from the maturity of marketable securities
                
                
                5,111
                
                
                
                15,740Investment
      in marketable securities
                
                
                -
                
                
                
                (8,739
                )Net
      cash (used in) provided by investing activities
                
                
                (482
                )
                
                
                3,336Cash
      flows from financing activitiesDistributions
                
                
                -
                
                
                
                (2,439
                )Net
      cash used in financing activities
                
                
                -
                
                
                
                (2,439
                )Net
      (decrease) increase in cash and cash equivalents
                
                
                (330
                )
                
                
                2,013Cash
      and cash equivalents, beginning of period
                
                
                8,163
                
                
                
                7,508Cash
      and cash equivalents, end of period
                
                $
                7,833
                
                
                $
                9,521Supplemental
      schedule of non-cash investing activitiesAdvances
      used for capital expenditures in oil and gas
                  properties
      reclassified to proved properties
                
                $
                66
                
                
                $
                -The
      accompanying notes are an integral part of these unaudited condensed
      financial statements.


5


RIDGEWOOD
ENERGY M FUND, LLC


NOTES TO UNAUDITED CONDENSED FINANCIAL STATEMENTS








1.
            Organization
      and Purpose





The
Ridgewood Energy M Fund, LLC (the “Fund”), a Delaware limited liability company,
was formed on August 2, 2004 and operates pursuant to a limited liability
company agreement (the “LLC agreement”) dated as of September 7, 2004 by and
among Ridgewood Energy Corporation (the “Manager”) and the shareholders of the
Fund. The Fund was organized to acquire interests in oil and natural gas
properties located in the United States offshore waters of Texas, Louisiana, and
Alabama in the Gulf of Mexico.





The
Manager performs, or arranges for the performance of, the management and
administrative services required for Fund operations. Such services include,
without limitation, the administration of shareholder accounts, shareholder
relations and the preparation, review and dissemination of tax and other
financial information.  In addition, the Manager provides office
space, equipment and facilities and other services necessary for Fund
operations.  The Manager also engages and manages the contractual
relations with unaffiliated custodians, depositories, accountants, attorneys,
broker-dealers, corporate fiduciaries, insurers, banks and others as required
(Notes 2, 6 and 8).





2.
            Summary
      of Significant Accounting Policies





Basis
of Presentation


These
unaudited interim condensed financial statements have been prepared by the
Fund’s management in accordance with accounting principles generally accepted in
the United States of America (“GAAP”) and in the opinion of management, contain
all adjustments (consisting of only normal recurring adjustments) necessary to
present fairly the Fund’s financial position, results of operations and cash
flows for the periods presented.  Certain information and note
disclosures normally included in annual financial statements prepared in
accordance with GAAP have been omitted in these unaudited interim condensed
financial statements.  The results of operations, financial position,
and cash flows for the periods presented herein are not necessarily indicative
of future financial results.  These unaudited interim condensed
financial statements should be read in conjunction with the annual financial
statements and the notes thereto for the year ended December 31, 2007 included
in the Fund’s Annual Report on Form 10-K filed with the Securities and Exchange
Commission (the “SEC”).





Use
of Estimates


The
preparation of financial statements in conformity with GAAP requires management
to make estimates and assumptions that affect the reported amounts of assets and
liabilities and disclosure of contingent assets and liabilities as of the date
of the financial statements and the reported amounts of revenues and expenses
during the reporting period. On an ongoing basis, the Manager reviews its
estimates, including those related to amounts advanced to and billed by
operators, determination of proved reserves, impairments and asset retirement
obligations.  Actual results may differ from those estimates.





Cash
and Cash Equivalents


All
highly liquid investments with maturities when purchased of three months or less
are considered cash and cash equivalents. At times, bank deposits may be in
excess of federally insured limits.  At June 30, 2008 and December 31,
2007, bank balances, inclusive of the salvage fund, exceeded federally insured
limits by $7.7 million and $8.0 million, respectively.  The Fund
maintains bank deposits with accredited financial institutions.





Investments
in Marketable Securities


At times
the Fund may purchase investments comprised of U. S. Treasury Bills and
Notes.  These investments are considered short-term when their
maturities, when purchased, are greater than three months and one year or less,
and long-term when their maturities are in excess of twelve months.  At
December 31, 2007, the Fund had short-term held-to-maturity investments totaling
$5.1 million.  Held-to-maturity securities are those investments that
the Fund has the ability and intent to hold until maturity, and are recorded at
cost plus accrued income, adjusted for the amortization of premiums and
discounts, which approximate fair value.  At June 30, 2008, the Fund
had no short-term investments in marketable securities.





6




For all
investments, interest income is accrued as earned and amortization of premium or
discount, if any, is included in interest income.





Salvage
Fund


Pursuant
to the Fund’s LLC Agreement, the Fund deposits in a separate interest-bearing
account, or a salvage fund, money to provide for dismantling production
platforms and facilities, plugging and abandoning the wells and removing the
platforms, facilities and wells after their useful lives, in accordance with
applicable federal and state laws and regulations.  At June 30, 2008
and December 31, 2007, the Fund had held-to-maturity investment within its
salvage fund totaling $1.1 million.  The held-to-maturity investment
held within the salvage fund at June 30, 2008 matures in February
2012.





Interest
earned on the account will become part of the salvage fund.  There are
no restrictions on withdrawals from the salvage fund.





Oil
and Gas Properties


Oil and
gas properties are operated by unaffiliated entities (“Operators”) who are
responsible for drilling, administering and producing activities pursuant to the
terms of the applicable operating agreements with working interest
owners.  The Fund's portion of exploration, drilling, operating and
capital equipment expenditures relating to the wells are advanced and billed by
Operators through authorization for expenditures.





The
successful efforts method of accounting for oil and gas producing activities is
followed. Acquisition costs are capitalized when incurred.  Other oil
and gas exploration costs, excluding the costs of drilling exploratory wells,
are charged to expense as incurred.  The costs of drilling exploratory
wells are capitalized pending the determination of whether the wells have
discovered proved commercial reserves.  If proved commercial reserves
have not been found, exploratory drilling costs are expensed to dry-hole
expense.  Costs to develop proved reserves, including the costs of all
development wells and related facilities and equipment used in the production of
crude oil and gas, are capitalized.  Expenditures for ongoing repairs
and maintenance of producing properties are expensed as incurred.





Upon the
sale or retirement of a proved property, the cost and related accumulated
depletion and amortization will be eliminated from the property accounts, and
the resultant gain or loss is recognized.  On the sale or retirement
of an unproved property, gain or loss on the sale is recognized.  The
Manager does not currently intend to sell any of the Fund’s property
interests.





Capitalized
acquisition costs of producing oil and gas properties are depleted by the
units-of-production method.





As of
June 30, 2008, $1.2 million was recorded in due to operators related to capital
expenditures for oil and gas property, which was paid during the third quarter
of 2008.





Advances
to Operators for Working Interests and Expenditures


The
Fund’s acquisition of a working interest in a well or a project requires it to
make a payment to the seller for the Fund’s right, title and
interest.  The Fund is also required to advance its share of estimated
cash expenditures for the succeeding month’s operation. The Fund accounts for
such payments as advances to operators for working interests and
expenditures.  As drilling costs are incurred, the advances are
transferred to unproved properties.





Asset
Retirement Obligations


For oil
and gas properties, there are obligations to perform removal and remediation
activities when the properties are retired.  When a project reaches
drilling depth and is determined to be either proved or dry, an asset retirement
obligation is incurred.  Plug and abandonment costs associated with
unsuccessful properties are expensed as dry-hole costs.  The table
below presents changes in the asset retirement obligations for the six months
ended June 30, 2008 and the year ended December 31, 2007.





7




June
      30, 2008
              
              
              December
      31, 2007(in
      thousands)Balance,
      beginning of period
              
              $
              476
              
              
              $
              225Liabilities
      incurred
              
              
              338
              
              
              
              291Revision
      to prior estimate
              
              
              -
              
              
              
              16Liabilities
      settled
              
              
              (139
              )
              
              
              (69
              )Accretion
      expense
              
              
              6
              
              
              
              13Balance,
      end of period
              
              $
              681
              
              
              $
              476


As
indicated above, the Fund maintains a salvage fund to provide for the funding of
future asset retirement obligations.





Syndication
Costs


Direct
costs associated with offering the Fund’s shares including professional fees,
selling expenses and administrative costs payable to the Manager, an affiliate
of the Manager and unaffiliated broker-dealers are reflected as a reduction of
shareholders’ capital.





Revenue
Recognition and Imbalances


Oil and
gas revenues are recognized when production is sold to a purchaser at a
fixed or determinable price, when delivery has occurred and title has
transferred, and if collectibility of the revenue is
probable.





The Fund
uses the sales method of accounting for gas production imbalances. The volumes
of gas sold may differ from the volumes to which the Fund is entitled based on
its interests in the properties. These differences create imbalances that are
recognized as a liability only when the properties’ estimated remaining reserves
net to the Fund will not be sufficient to enable the underproduced owner to
recoup its entitled share through production. The Fund’s recorded liability, if
any, would be reflected in other non-current liabilities. No receivables are
recorded for those wells where the Fund has taken less than its share of
production. Gas imbalances are reflected as adjustments to estimates of proved
gas reserves and future cash flows.  At June 30, 2008 and December 31,
2007, there were no oil or gas balancing arrangements between the Fund and other
working interest owners.





Impairment
of Long-Lived Assets


In
accordance with the Statement of Financial Accounting Standards (“SFAS”) No.
144, “Accounting for the Impairment of Long-Lived Assets”, long-lived
assets, such as oil and gas properties, are evaluated when events or changes in
circumstances indicate the carrying value of such assets may not be recoverable.
The determination of whether impairment has occurred is made by comparing the
carrying values of long-lived assets to the estimated future undiscounted
cash flows attributable to the asset. The impairment loss recognized is the
excess of the carrying value over the future discounted cash flows attributable
to the asset or the estimated fair value of the asset.  For the three and
six months ended June 30, 2008 and 2007, no impairments have been
recorded.  During the six months ended June 30, 2008, the Fund
recorded a credit from the operator of $0.5 million upon review of well costs
related to the previously impaired Eugene Island 364 project.





Depletion
and Amortization


Depletion
and amortization of the cost of proved oil and natural gas properties are
calculated using the units-of-production method.  Proved developed
reserves are used as the base for depleting the cost of successful exploratory
drilling and development costs.  The sum of proved developed and
proved undeveloped reserves is used as the base for depleting, or amortizing,
leasehold acquisition costs, the costs to acquire proved properties, platform
and pipeline costs.





Income
Taxes


No
provision is made for income taxes in the financial statements.  The
Fund is a limited liability company, and as such the Fund’s income or loss is
passed through and included in the tax returns of the Fund’s
shareholders.





Income
and Expense Allocation


Profits
and losses are allocated 85% to shareholders in proportion to their relative
capital contributions and 15% to the Manager, except for interest income and
certain expenses such as dry hole costs, fiduciary fees, depletion and
amortization which are allocated 99% to shareholders and 1% to the
Manager.




8




3.
            Recent
      Accounting Standards





In May
2008, the Financial Accounting Standards Board (“FASB”) issued SFAS No. 162,
“The Hierarchy of Generally Accepted Accounting Principles,” (“SFAS No.162”),
which identifies the sources of accounting principles and the framework for
selecting the principles used in the preparation of financial statements that
are presented in conformity with GAAP.  SFAS No. 162 will be effective
sixty days following the Securities and Exchange Commission’s approval of the
Public Company Accounting Oversight Board amendments to AU Section
411.  The Fund does not expect the adoption of SFAS No. 162 will have
a material impact on its financial condition or results of
operation.





In
September 2006, the FASB issued SFAS No. 157, “Fair Value Measurements,” (“SFAS
No.157”), which applies under most other accounting pronouncements that require
or permit fair value measurements. SFAS No. 157 provides a common definition of
fair value as the price that would be received to sell an asset or paid to
transfer a liability in a transaction between market participants. The new
standard also provides guidance on the methods used to measure fair value and
requires expanded disclosures related to fair value
measurements.  SFAS No. 157 had originally been effective for
financial statements issued for fiscal years beginning after November 15, 2007,
however the FASB has agreed on a one year deferral for all non-financial assets
and liabilities. On January 1, 2008, the Fund adopted SFAS No.157 for financial
assets and liabilities.





4.
            Unproved
      Properties - Capitalized Exploratory Well
Costs





Leasehold
acquisition and exploratory drilling costs are capitalized pending determination
of whether the well has found proved reserves.  Unproved properties
are assessed on a quarterly basis by evaluating and monitoring if sufficient
progress is made on accessing the reserves.





As of
June 30, 2008, the Fund had two properties, Vermilion 344 and South Marsh Island
111, with capitalized expenditures in excess of one year.  Both
projects have been determined to be successful, and production facilities are
being completed, with production expected during the fourth quarter of
2008.  Capitalized costs related to Vermillion 344 at June 30, 2008
and December 31, 2007 were $2.1 million and $1.1 million,
respectively.    Capitalized costs related to South Marsh
Island 111 at June 30, 2008 and December 31, 2007 were $1.6 million and $1.0
million, respectively.  The following table reflects the net changes
in unproved properties for the six months ended June 30, 2008 and the year ended
December 31, 2007.




June
      30, 2008
              
              
              December
      31, 2007(in
      thousands)Balance,
      beginning of period
              
              $
              7,357
              
              
              $
              5,355Additions
      to capitalized exploratory well costs pending the
                determination
      of proved reserves
              
              
              3,470
              
              
              
              7,960Reclassification
      to proved properties based on the
                determination
      of proved reserves
              
              
              (7,133
              )
              
              
              (5,958
              )Capitalized
      exploratory well costs charged to dry-hole costs
              
              
              -
              
              
              
              -Balance,
      end of period
              
              $
              3,694
              
              
              $
              7,357




Capitalized
costs are expensed as dry-hole costs in the event that reserves are not found or
are not in sufficient quantities to complete the well and develop the
field.  During the three and six months ended June 30, 2007, the Fund
received credits from Operators of certain wells based upon review and audits of
the wells costs performed by working interest owners. Dry-hole costs are
detailed in the table below.





9






Three
      months ended June 30,
              
              
              Six
      months ended June 30,Lease
      Block
              
              2008
              
              
              2007
              
              
              2008
              
              
              2007(in
      thousands)South
      Marsh 213
              
              $
              1,251
              
              
              $
              -
              
              
              $
              1,688
              
              
              $
              -Main
      Pass 155
              
              $
              -
              
              
              $
              (46
              )
              
              $
              -
              
              
              $
              (46
              )Other
              
              
              5
              
              
              
              -
              
              
              
              15
              
              
              
              -$
              1,256
              
              
              $
              (46
              )
              
              $
              1,703
              
              
              $
              (46
              )




5.
            Distributions





Distributions
to shareholders are allocated in proportion to the number of shares
held.





The
Manager will determine whether available cash from operations, as defined in the
Fund's LLC Agreement, is to be distributed.  Such distributions are
allocated 85% to the shareholders and 15% to the Manager, as defined in the
Fund's LLC Agreement.





Available
cash from dispositions, as defined in the Fund's LLC Agreement, will be paid 99%
to shareholders and 1% to the Manager until the shareholders have received total
distributions equal to their capital contributions. After shareholders have
received distributions equal to their capital contributions, 85% of available
cash from dispositions will be distributed to shareholders and 15% to the
Manager.





There
were no distributions paid to the shareholders or the Manager for the six months
ended June 30, 2008.  Distributions to the Fund’s shareholders and the
Manager during the six months ended June 30, 2007 were $2.1 million and $0.4
million, respectively.





6.
            Related
      Parties





The
Fund’s LLC Agreement provides that the Manager render management, administrative
and advisory services, for which the Manger received a management
fee.  Beginning on October 1, 2007 and continuing for the remaining
life of the Fund, the Manager elected to waive its management
fee.  Management fees of $0.3 million and $0.6 million were incurred
for the three and six months ended June 30, 2007, respectively.  Upon
the waiver of the management fee, the Fund began recording costs relating to
services provided by the Manager for accounting and investor
relations.  Such costs totaled $20 thousand and $40 thousand for the
three and six months ended June 30, 2008, respectively, and were included in
general and administrative expenses.




From time
to time, short-term payables and receivables, which do not bear interest, arise
from transactions with affiliates in the ordinary course of
business.  At June 30, 2008 the Fund owed the Manager $23 thousand
related to insurance.  As of December 31, 2007 the Fund owed the
Manager $6 thousand relating to revenue allocations.  These amounts
are included in accrued expenses payable at June 30, 2008 and December 31,
2007.





None of
the compensation to be received by the Manager has been derived as a result of
arm’s length negotiations.





The Fund
has working interest ownership in certain projects to acquire and develop oil
and natural gas projects with other entities that are likewise managed by the
Manager.





7.
            Fair
      Value of Financial Instruments and
Measurements





As of
June 30, 2008 and December 31, 2007, the carrying values of cash and cash
equivalents, short-term investments in marketable securities, salvage fund,
production receivable and accrued expenses approximated fair value.





10




8.
            Commitments
      and Contingencies





Capital
Commitments


The Fund
has entered into multiple offshore operating agreements for the drilling and
development of its investment properties. The estimated capital expenditures
associated with these agreements vary depending on the stage of development on a
property-by-property basis. As of June 30, 2008, the Fund had committed to spend
an additional $2.3 million relating to the properties.





Environmental
Considerations


The
exploration for and development of oil and natural gas involves the extraction,
production and transportation of materials which, under certain conditions, can
be hazardous or cause environmental pollution problems.  The Manager
and the Operators are continually taking action they believe appropriate to
satisfy applicable federal, state and local environmental regulations and do not
currently anticipate that compliance with federal, state and local environmental
regulations will have a material adverse effect upon capital expenditures,
results of operations or the competitive position of the Fund in the oil and
natural gas industry.  However, due to the significant public and
governmental interest in environmental matters related to those activities, the
Manager cannot predict the effects of possible future legislation, rule changes,
or governmental or private claims.  At June 30, 2008 and December 31,
2007, there were no known environmental contingencies that required the Fund to
record a liability.





Insurance
Coverage


The Fund
is subject to all risks inherent in the exploration for and development of oil
and natural gas. Insurance coverage as is customary for entities engaged in
similar operations is maintained, but losses may occur from uninsurable risks or
amounts in excess of existing insurance coverage. The occurrence of an event
which is not insured or not fully insured could have an adverse impact upon
earnings and financial position.  Moreover, insurance is obtained as a
package covering all of the Manager’s investment programs.  Claims
made by other such programs can reduce or eliminate insurance for the
Fund.











11




ITEM 2.  MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL
CONDITION AND RESULTS OF OPERATIONS





Cautionary
Statement Regarding Forward-Looking Statements





Certain
statements in this quarterly report on Form 10-Q (“Quarterly Report”) and
the documents Ridgewood Energy M Fund, LLC (the “Fund”) has incorporated by
reference into this Quarterly Report, other than purely historical information,
including estimates, projections, statements relating to the Fund’s business
plans, strategies, objectives and expected operating results, and the
assumptions upon which those statements are based, are “forward-looking
statements” within the meaning of the Private Securities Litigation Reform Act
of 1995, Section 27A of the Securities Act of 1933, as amended (the
“Securities Act”) and Section 21E of the Securities Exchange Act of 1934
(the “Exchange Act”). These forward-looking statements generally are identified
by the words “believe,” “project,” “expect,” “anticipate,” “estimate,” “intend,”
“strategy,” “plan,” “target,” “pursue,” “may,” “will,” “would,” “will be,” “will
continue,” “will likely result,” and similar expressions. Forward-looking
statements are based on current expectations and assumptions that are subject to
risks and uncertainties which may cause actual results to differ materially from
the forward-looking statements.  Examples of such events that could
cause actual results to differ materially from historical results or those
anticipated include weather conditions, such as hurricanes, changes in market
conditions affecting the pricing of oil and natural gas, the cost and
availability of equipment, and changes in governmental
regulations.  The Fund undertakes no obligation to update or revise
publicly any forward-looking statements, whether as a result of new information,
future events or otherwise.





Critical
Accounting Policies and Estimates





The
following discussion and analysis of the Fund’s financial condition and
operating results is based on the Fund’s financial statements.  The
preparation of this Quarterly Report requires the Fund to make estimates and
assumptions that affect the reported amount of assets and liabilities,
disclosure of contingent assets and liabilities at the date of the Fund’s
financial statements, and the reported amount of revenue and expenses during the
reporting period. Actual results may differ from those estimates and
assumptions.  See “Notes to Unaudited Condensed Financial Statements”
in Part I of this Quarterly Report for a presentation of the Fund’s significant
accounting policies.   No changes have been made to the Fund’s
critical accounting policies and estimates disclosed in its 2007 Annual Report
on Form 10-K.





Overview
of the Fund’s Business





The Fund
is a Delaware limited liability company formed on August 2, 2004 to acquire
interests primarily in oil and natural gas projects located in the U.S. waters
of the Gulf of Mexico. Ridgewood Energy Corporation (“Ridgewood Energy” or the
“Manager”) a Delaware corporation, is the Manager. As the Manager, Ridgewood
Energy has direct and exclusive control over the management and control of Fund
operations. The Fund is an independent oil and natural gas producer. The
Fund’s primary investment objective is to generate cash flow for distribution to
the Fund’s shareholders through participation in oil and natural gas exploration
and development projects in the Gulf of Mexico.





The
Manager performs certain duties on the Fund’s behalf including the evaluation of
potential projects for investment and ongoing management, administrative and
advisory services associated with these projects.  For these services,
the Manager has received an annual management fee, ranging from 1% to 2.5%
of total capital contributions, net of cumulative dry-hole and related well
costs.  As of October 1, 2007, the Manager has elected to cease
collecting its management fee for the remaining life of the Fund. The Fund does
not currently, nor is there any plan to operate any project in which the Fund
participates.  The Manager enters into operating agreements with
third-party operators (the “Operators”) for the management of all exploration,
development and producing operations, as appropriate.  The Manager
also participates in distributions.





Business
Update





The Fund
owns working interests and has participated in the drilling of fourteen
wells.  Four wells are currently producing and completion efforts are
ongoing for three wells.  The remaining seven wells have been
determined to be dry-holes or have been abandoned.




12




Successful
Projects




West
Cameron 57


In
September 2007, the Fund acquired a 12.5% working interest in the West Cameron
57 project from Chevron U.S.A., Inc. (“Chevron”), the
operator.  Drilling began in October 2007, and the well was determined
to be a success in February 2008.  Completion efforts are currently in
process, and production is expected in September
2008.  Through June 30, 2008, the Fund has spent $4.5 million on
this well, for which the total estimated budget is $5.4 million





West
Cameron 77 #2 (Mustang)


In 2004,
the Fund acquired a 14.54% working interest in the West Cameron 77 #2 Mustang
project from BHP Billiton Petroleum (“BHP”), the operator.  The well
began production in May 2006.  During the fourth quarter of 2007
production in the lower reservoir zone ceased and in early-2008 BHP re-completed
the upper reservoir zone.  Production resumed in February 2008,
however the well is currently off-line after experiencing a decline in well
pressure. The
Fund and BHP believe that there are substantial reserves remaining for this well
and are in the process of evaluating the maintenance plan necessary to
resume production.  The total cost of the property was $8.8
million.  During the six months ended June 30, 2008, the Fund incurred
$0.9 million of workover costs related to this well.





LLOG
Projects


In
October 2006, the Fund acquired an 8.75% working interest in six exploratory
wells to be drilled by LLOG Exploration Company (“LLOG”), the operator, off the
coast of Louisiana.  Of the six wells, the Fund elected not to proceed
with one well and one well was determined to be a dry hole





The
remaining four LLOG wells, as detailed below, have been determined to be
successful and completion efforts are ongoing for two wells.  The
total budget for these projects is $7.9 million, of which $6.6 million has been
spent at June 30, 2008.





South
      Marsh Island 111
            Discovery
      July 2007; Production
              expected
      November 2008Vermilion
      344
            Discovery
      January 2007;
              Production
      expected October 2008West
      Delta 68
            Discovery
      March 2007;
              Production
      commenced July 2008West
      Delta 67
            Discovery
      November 2007;
              Production
      commenced July 2008





Currently
Producing





Eugene Island
337


In 2006,
the Fund acquired a 20% working interest in the Eugene Island 337 project
from Devon Energy Corporation (“Devon”), the operator.  The property
was determined to be a commercial success in July 2006.  The total
cost of this property was $6.1 million, of which impairment costs totaling $4.9
million were recorded during the year ended December 31, 2007.  No
impairments were taken during the three and six months ended June 30, 2008 and
2007.





Dry
Holes / Abandonment





South
Marsh Island 213


In March
2008, the Fund acquired a 5.5% working interest in the exploratory project South
Marsh Island 213 from LLOG, the operator.  This project began drilling
in March 2008.  On April 30, 2008 the Fund was informed by LLOG that
the well being drilled on the South Marsh Island 213 lease block did not have
commercially productive quantities of either natural gas or oil and had been
deemed an unsuccessful well, or dry hole.  Dry-hole costs related to
this well, including plug and abandonment expenses, for the six months ended
June 30, 2008 were $1.7 million.





Eugene Island
364


In 2006,
the Fund acquired a 50% working interest in Eugene Island 364 from El Paso
E&P Company (“El Paso”), the operator.  The well produced for a
short time in 2006 but had been shut-in since August 2006 due to mechanical
problems.  At December 31, 2007, the Fund concluded that it was
no longer economical to proceed with recovery efforts and the well was
abandoned.  The total cost of this property was $13.3 million, of
which impairment costs totaling $11.4 million were recorded during the year
ended December 31, 2007.  During the six months ended June 30, 2008,
the Eugene Island 364 project received credits totaling $0.5 million from the
operator upon review of the well costs.  No impairments were taken
during the three and six months ended June 30, 2008.




13




Results
of Operations





The
following review of operations for the three and six months ended June 30, 2008
and 2007 should be read in conjunction with the Fund’s financial statements and
the notes thereto.




Three
      months ended June 30,
              
              
              Six
      months ended June 30,2008
              
              
              2007
              
              
              2008
              
              
              2007(in
      thousands)RevenueOil
      and gas revenue
              
              $
              182
              
              
              $
              1,175
              
              
              $
              628
              
              
              $
              2,553ExpensesDepletion
      and amortization
              
              
              82
              
              
              
              386
              
              
              
              318
              
              
              
              775Dry-hole
      costs
              
              
              1,256
              
              
              
              (46
              )
              
              
              1,703
              
              
              
              (46
              )Management
      fees to affiliate
              
              
              -
              
              
              
              322
              
              
              
              -
              
              
              
              645Impairment
      of proved property
              
              
              -
              
              
              
              -
              
              
              
              (471
              )
              
              
              -Operating
      expenses
              
              
              38
              
              
              
              235
              
              
              
              957
              
              
              
              628General
      and administrative expenses
              
              
              123
              
              
              
              132
              
              
              
              274
              
              
              
              314Total
      expenses
              
              
              1,499
              
              
              
              1,029
              
              
              
              2,781
              
              
              
              2,316(Loss)
      income from operations
              
              
              (1,317
              )
              
              
              146
              
              
              
              (2,153
              )
              
              
              237Other
      incomeInterest
      income
              
              
              48
              
              
              
              256
              
              
              
              136
              
              
              
              535Net
      (loss) income
              
              $
              (1,269
              )
              
              $
              402
              
              
              $
              (2,017
              )
              
              $
              772




Oil and Gas
Revenue.During the three and six
months ended June 30, 2008, the Fund had two producing wells, West Cameron 77
Mustang and Eugene Island 337, which came onto production in May 2006 and
November 2007, respectively.  Oil and gas revenue for the three months
ended June 30, 2008 was $0.2 million, a $1.0 million decrease from the three
months ended June 30, 2007.   The decrease is attributable to a
decrease in production and sales volumes of $1.1 million, partially offset by
the impact of increased average prices of $0.1 million.





The
Fund’s wells produced 34 barrels of oil during the three months ended June 30,
2008.  During the three months ended June 30, 2007, oil production was
approximately 2 thousand barrels.  The Fund’s oil prices averaged
approximately $114 per barrel during the three months ended June 30, 2008
compared to $67 per barrel during the three months ended June 30,
2007.





Natural
gas production during the three months ended June 30, 2008 was approximately 14
thousand mcf compared to 135 thousand mcf, during the three months ended June
30, 2007.    During the three months ended June 30, 2008,
the Fund’s natural gas prices averaged $12.95 per mcf compared to $8.07 per mcf
during the three months ended June 30, 2007.





Oil and
gas revenue for the six months ended June 30, 2008 was $0.6 million, a $2.0
million decrease from the six months ended June 30, 2007.   The
decrease is attributable to a decrease in production and sales volumes totaling
$2.1 million offset by the impact of increased average prices totaling $0.1
million.





The
Fund’s wells produced approximately 300 hundred barrels of oil during the six
months ended June 30, 2008.  During the six months ended June 30,
2007, oil production was approximately 4 thousand barrels.  The Fund’s
oil prices averaged approximately $99 per barrel during the six months ended
June 30, 2008 compared to $62 per barrel during the six months ended June 30,
2007.




14




Natural
gas production during the six months ended June 30, 2008 was approximately 58
thousand mcf compared to 308 thousand mcf, during the six months ended June 30,
2007.    During the six months ended June 30, 2008, the
Fund’s natural gas prices averaged $10.22 per mcf compared to approximately
$7.63 per mcf during the three months ended June 30, 2007.





The
decrease in sales volumes for both the three and six months ended June 30, 2008
was principally attributable to the West Cameron 77 Mustang well, which is
currently off-line while the Fund and BHP determine a maintenance
plan.





Depletion and
Amortization.  Depletion and amortization for the three and six
months ended June 30, 2008 was $0.1 million and $0.3 million, respectively,
which represents a decrease of $0.2 million and $0.4 million compared to the
three and six months ended June 30, 2007.  The decreases in depletion
and amortization resulted from a decline in production from the West
Cameron 77 Mustang well, partially offset by the Eugene Island 337 well coming
on production in November 2007.





Dry-hole
Costs.Dry-hole costs are those
costs incurred to drill and develop a well that is ultimately found to be
incapable of producing either oil or natural gas in sufficient quantities to
justify completion of the well. During the three and six months ended June 30,
2007, the Fund received credits from operators of certain wells based upon
review and audits of the wells costs performed by working interest owners. The
following table summarizes dry-hole costs inclusive of plug and abandonment
costs.




Three
      months ended June 30,
              
              
              Six
      months ended June 30,Lease
      Block
              
              2008
              
              
              2007
              
              
              2008
              
              
              2007(in
      thousands)South
      Marsh 213
              
              $
              1,251
              
              
              $
              -
              
              
              $
              1,688
              
              
              $
              -Main
      Pass 155
              
              $
              -
              
              
              $
              (46
              )
              
              $
              -
              
              
              $
              (46
              )Other
              
              
              5
              
              
              
              -
              
              
              
              15
              
              
              
              -$
              1,256
              
              
              $
              (46
              )
              
              $
              1,703
              
              
              $
              (46
              )




Management
Fees
to Affiliate.Management fees
for the three and six months ended June 30, 2007 were $0.3 million and $0.6
million, respectively.  Management fees are charged to cover expenses
associated with overhead incurred by the Manager for its ongoing management,
administrative and advisory services.  Such overhead expenses include
but are not limited to rent, payroll and benefits for employees of the Manager,
and other administrative costs. Beginning on October 1, 2007 and continuing for
the remaining life of the Fund, the Manager elected to waive its management
fee.





Impairment of
Proved Property.During the six months ended June 30, 2008,
the previously impaired Eugene Island 364 project received credits totaling $0.5
million from the operator upon review of the well costs.





Operating
Expenses.  Operating expenses are comprised of geological and
geophysical costs associated with the Fund’s acquisition of oil and gas
properties and accretion expense related to asset retirement obligations. For
the three months ended June 30, 2008 and 2007, operating expenses were $38
thousand and $0.2 million, respectively.  The decrease for three
months ended June 30, 2008 is attributable to $0.2 million of workover costs on
Eugene Island 364 during 2007.  This well was abandoned during the
fourth quarter of 2007. For the six months ended June 30, 2008 and 2007,
operating expenses were $1.0 million and $0.6 million,
respectively.  The increase for six months ended June 30, 2008 is
attributable to $0.9 million of workover costs associated with the West Cameron
77 Mustang well coupled with the onset of  production of Eugene Island
337, partially offset by the decrease in Eugene Island 364.





15




General
and Administrative Expenses.General and administrative expenses
represent costs specifically identifiable or allocable to the Fund as detailed
in the schedule below.




Three
      months ended June 30,
              
              
              Six
      months ended June 30,2008
              
              
              2007
              
              
              2008
              
              
              2007(in
      thousands)Insurance
              
              $
              54
              
              
              $
              56
              
              
              $
              116
              
              
              $
              184Accounting
              
              
              43
              
              
              
              67
              
              
              
              108
              
              
              
              112Management
      reimbursement
              
              
              20
              
              
              
              -
              
              
              
              40
              
              
              
              -Trust
      fees and other
              
              
              6
              
              
              
              9
              
              
              
              10
              
              
              
              18$
              123
              
              
              $
              132
              
              
              $
              274
              
              
              $
              314







Insurance
expense represents premiums related to well control insurance, which varies
dependent upon drilling activity, and directors and officers liability policy,
which is allocated by the Manager to the Fund based on capital raised by the
Fund to total capital raised by all oil and natural gas funds managed by the
Manager.  Accounting fees represent annual audit and tax preparation
fees, quarterly reviews and filing fees of the Fund.  Management
reimbursement relates to a reimbursement to the Manager by the Fund for various
administrative costs incurred by the Manager on the Fund’s behalf for the three
and six months ended June 30, 2008.  Trust fees represent bank fees
associated with the management of the Fund’s cash accounts.





Interest
Income.Interest
income is comprised of interest earned on money market accounts and investments
in U.S. Treasury securities.  For the three months ended June 30, 2008
and 2007 interest income was $48 thousand and $0.3 million,
respectively.  For the six months ended June 30, 2008 and 2007
interest income was $0.1 million and $0.5 million, respectively.  The
decreases during the three and six months ended June 30, 2008
were  attributable to decreases in the average outstanding balances
earning interest due to property expenditures during the period, coupled with
lower interest rates.





Capital
Resources and Liquidity





Operating Cash
Flows


Cash
flows provided by operating activities for the six months ended June 30, 2008,
were $0.2 million, primarily related to revenue received of $0.6 million,
credits received on a previously impaired well of $0.5 million and interest
received of $0.1 million.  These amounts were partially offset by
operating expenses paid of $0.7 million and general and administrative expenses
of $0.3 million.





Cash
flows provided by operating activities for the six months ended June 30, 2007
were $1.1 million, primarily related to revenue received of $2.6 million and
interest received of $0.2 million, partially offset by  management
fees of $0.7 million, operating expenses of $0.6 million, general and
administrative expenses of $0.3 million, and unfavorable working capital of $0.1
million.





Investing
Cash Flows


Cash
flows used in investing activities for the six months ended June 30, 2008 were
$0.5 million, primarily related to proceeds from the maturity of marketable
securities of $5.1 million, offset by capital expenditures for oil and gas
properties of $5.6 million.  In the six months ended June 30, 2008,
the Fund increased its salvage fund investments by $15 thousand, which consisted
of the interest earned on this fund.





Cash
flows provided by investing activities for the six months ended June 30, 2007
were $3.3 million, primarily related to the proceeds from the maturity of
marketable securities of $15.7 million partially offset by capital expenditures
for oil and gas properties of $3.6 million and investments in marketable
securities of $8.7 million.  In the six months ended June 30, 2007,
the Fund increased its salvage fund investments by $17 thousand, which consisted
of the interest earned on this account.





Financing
Cash Flows


There
were no cash flows used in financing activities for the six months ended June
30, 2008.




16




Cash
flows used in financing activities for the six months ended June 30, 2007 were
$2.4 million, related to distributions paid to the Manager and
shareholders.








Estimated
Capital Expenditures





The Fund
has entered into multiple offshore operating agreements for the drilling and
development of its investment properties.  The estimated capital
expenditures associated with these agreements can vary depending on the stage of
development on a property-by-property basis.  As of June 30, 2008, the
Fund had commitments related to authorizations for expenditures totaling $2.3
million for properties.





When the
Manager makes a decision for participation in a particular project, it assumes
that the well will be successful and allocates enough capital to budget for the
completion of that well and the additional development wells and infrastructure
anticipated. If an exploratory well is deemed a dry hole or if it is
un-economical, the capital allocated to the completion of that well and to the
development of additional wells is then reallocated to a new project or used to
make additional investments.





Liquidity
Needs





The
Fund’s primary short-term liquidity needs are to fund its operations including
capital expenditures with existing cash on-hand and income earned from its
short-term investments and cash and cash equivalents.





Distributions,
if any, are funded from cash flow from operations, and the frequency and amount
are within the Manager’s discretion subject to available cash from operations,
reserve requirements and Fund operations.





The
capital raised by the Fund in its private placement is more than likely all the
capital it will be able to obtain for investments in projects. The number of
projects in which the Fund can invest will naturally be limited and each
unsuccessful project the Fund experiences, if any, will not only reduce its
ability to generate revenue, but also exhaust its limited supply of capital.
Typically the Manager seeks an investment portfolio that combines high and low
risk exploratory projects.








Off-Balance Sheet Arrangements





The Fund
had no off-balance sheet arrangements as of June 30, 2008 and December 31, 2007
and does not anticipate the use of such arrangements in the future.





Contractual
Obligations





The Fund
enters into operating agreements with operators.  On behalf of the Fund, an
operator enters into various contractual commitments pertaining to exploration,
development and production activities.  The Fund does not discuss or
negotiate any such contracts. No contractual obligations exist at June 30, 2008
and December 31, 2007 other than those discussed in “Estimated Capital
Expenditures” above.





ITEM 3.  QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET
RISK





Not
required.





ITEM 4.  CONTROLS AND PROCEDURES





In
accordance with Exchange Act Rules 13a-15 and 15d-15, the Fund carried out
an evaluation, under the supervision and with the participation of management,
including its Chief Executive Officer and Chief Financial Officer, of the
effectiveness of our disclosure controls and procedures as of the end of the
period covered by this report.  Based on that evaluation, our Chief
Executive Officer and Chief Financial Officer concluded that the Fund’s
disclosure controls and procedures were effective as of June 30,
2008.




17




There has
been no change in the Fund’s internal control over financial reporting that
occurred during the three months ended June 30, 2008 that has materially
affected, or is reasonably likely to materially affect, the Fund’s internal
control over financial reporting.





PART II.  OTHER
INFORMATION





ITEM 1.
LEGAL PROCEEDINGS





There
have been no changes to the legal proceedings disclosed in the Fund’s most
recent Annual Report on Form 10-K.





ITEM1A. RISK
FACTORS





Not
required.





ITEM
2.  UNREGISTERED SALES OF EQUITY SECURITIES AND USE OF
PROCEEDS





None.





ITEM
3.  DEFAULTS UPON SENIOR
SECURITIES





None.





ITEM 4. SUBMISSIONS OF MATTERS TO
A VOTE OF SECURITY HOLDERS





None.





ITEM 5. OTHER
INFORMATION





None.





ITEM 6.EXHIBITS




Item
      6.
              
              Exhibits10.1
              
              Participation
      Agreement between El Paso E&P Company, L.P. and Ridgewood Energy
      Corporation as Manager and LLOG Exploration Offshore, Inc. for South Marsh
      Island Block 213. (previously filed)31.1
              
              Certification
      of Robert E. Swanson, Chief Executive Officer, pursuant to Securities
      Exchange Act Rule 13a-14(a).31.2
              
              Certification
      of Kathleen P. McSherry, Chief Financial Officer, pursuant to Securities
      Exchange Act Rule 13a-14(a).32
              
              Certifications
      pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of
      The Sarbanes-Oxley Act of 2002, signed by Robert E. Swanson, Chief
      Executive Officer of the Company and Kathleen P. McSherry, Chief Financial
      Officer of the Company.







18






SIGNATURES





Pursuant
to the requirements of the Securities Exchange Act of 1934, the Registrant has
caused this Form 10-Q to be signed on its behalf by the undersigned, thereunto
duly authorized.





Dated:
            August
      6, 2008
            
            
            
            RIDGEWOOD
      ENERGY M FUND, LLCBy:
            /s/
            
            ROBERT
      E. SWANSONName:
            
            Robert
      E. SwansonTitle:
            
            President
      and Chief Executive Officer(Principal
      Executive Officer)Dated:
            August
      6, 2008By:
            /s/
            
            KATHLEEN
      P. MCSHERRYName:
            
            Kathleen
      P. McSherryTitle:
            
            Executive
      Vice President and Chief Financial Officer(Principal
      Financial and Accounting Officer)










19