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 1934
         For the quarterly period ended June 30, 2006
                                       or

|_|  TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES
     EXCHANGE ACT OF 1934
     For the transition period from _________________to___________________


                        Commission File Number 000-51924

                          RIDGEWOOD ENERGY O FUND, LLC
             (Exact name of registrant as specified in its charter)


                 Delaware                                  76-0774429
     (State or other jurisdiction of                    (I.R.S. Employer
      incorporation or organization)                   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)


     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 |X| No |_|

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

 Large accelerated filer |_|   Accelerated filer |_|   Non-accelerated filer |X|

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

     As of November 21, 2006 there were 870.6486 shares of membership interest
of the registrant outstanding.



<PAGE>

                                Table of Contents

<TABLE>
<CAPTION>
Part I - FINANCIAL INFORMATION                                                                   Page
<S>                                                                                              <C>
     Item 1.  Financial Statements (Unaudited):
       Condensed Balance Sheets as of June 30, 2006 and December 31, 2005                           3
       Condensed Statements of Operations and Other Comprehensive Loss for the
          three months ended June 30, 2006 and 2005, for the six months ended
          June 30, 2006 and 2005, and for the period from December 21, 2004
          (Inception) to June 30, 2006                                                              4
       Condensed Statements of Cash Flows for the six months ended
          June 30, 2006 and 2005, and for the period from December 21, 2004
          (Inception) to June 30, 2006                                                              5
       Notes to Unaudited Condensed Financial Statements                                            6

     Item 2.  Management's Discussion and Analysis of Financial Condition                          16
        and Results of Operations
     Item 3.  Quantitative and Qualitative Disclosures About Market Risk                           23
     Item 4.  Controls and Procedures                                                              23

Part II - OTHER INFORMATION

     Item 5.  Other Information                                                                    26
     Item 6.  Exhibits                                                                             27

     SIGNATURES                                                                                    28
</TABLE>


                                       2

<PAGE>

Part I - Financial Information
Item 1.  Financial Statements

                          RIDGEWOOD ENERGY O FUND, LLC
                        (An exploratory stage enterprise)
                            CONDENSED BALANCE SHEETS
                                  (Unaudited)

<TABLE>
<CAPTION>
                                                                         June 30, 2006        December 31, 2005
                                                                         -------------        -----------------
                         ASSETS
<S>                                                                      <C>                    <C>
Current assets:
    Cash and cash equivalents                                            $  37,378,657          $   8,624,190
    Short-term investment in marketable securities                          40,274,641             73,914,750
    Interest receivable                                                              -                  2,455
    Prepaid expenses                                                            21,699                 55,957
                                                                         -------------          -------------
       Total current assets                                                 77,674,997             82,597,352
                                                                         -------------          -------------
Salvage fund                                                                 1,034,907              1,013,622
                                                                         -------------          -------------
Oil and gas properties
    Advances to operators for working interests and expenditures                     -              9,957,118
    Unproved properties                                                     20,809,854             16,873,053
                                                                         -------------          -------------
       Total oil and gas properties                                         20,809,854             26,830,171
                                                                         -------------          -------------
       Total assets                                                      $  99,519,758          $ 110,441,145
                                                                         =============          =============
            LIABILITIES AND MEMBERS' CAPITAL
Current liabilities:
    Due to operators                                                     $  12,237,407          $   3,073,419
    Accrued expenses payable                                                   382,727                 74,100
    Due to affiliates (Note 7)                                                   4,520                 28,063
                                                                         -------------          -------------
       Total current liabilities                                            12,624,654              3,175,582
                                                                         -------------          -------------
Commitments and contingencies (Note 9)

Members' capital:
    Manager:
       Deficit accumulated during the exploratory stage                       (839,670)              (392,705)
       Accumulated other comprehensive income                                        -                    451
                                                                         -------------          -------------
       Manager's total                                                        (839,670)              (392,254)
                                                                         -------------          -------------
    Shareholders:
       Capital contributions (935 shares authorized;
          870.6486 issued and outstanding)                                 128,989,688            128,989,688
       Syndication costs                                                   (14,741,924)           (14,741,924)
       Deficit accumulated during the exploratory stage                    (26,512,990)            (6,634,554)
       Accumulated other comprehensive income                                        -                 44,607
                                                                         -------------          -------------
       Shareholders' total                                                  87,734,774            107,657,817
                                                                         -------------          -------------
       Total members' capital                                               86,895,104            107,265,563
                                                                         -------------          -------------
       Total liabilities and members' capital                            $  99,519,758          $ 110,441,145
                                                                         =============          =============
</TABLE>

              The accompanying notes are an integral part of these
                         condensed financial statements.

                                       3

<PAGE>


                          RIDGEWOOD ENERGY O FUND, LLC
                        (An exploratory stage enterprise)
         CONDENSED STATEMENTS OF OPERATIONS AND OTHER COMPREHENSIVE LOSS
                                   (Unaudited)

<TABLE>
<CAPTION>
                                                                                                                    For the period
                                                                                                                     December 21,
                                                   Three months ended                   Six months ended           2004 (Inception)
                                                        June 30,                            June 30,                   through
                                                 2006              2005              2006              2005          June 30, 2006
                                                 ----              ----              ----              ----          -------------
<S>                                          <C>               <C>               <C>               <C>               <C>
Revenue
   Oil and gas revenue                       $          -      $          -      $          -      $          -      $          -
                                             ------------      ------------      ------------      ------------      ------------
Expenses
   Dry-hole costs                            $ 15,358,615               $ -      $ 20,280,417               $ -      $ 20,800,436
   Investment fees to affiliate (Note 7)                -         2,131,894                 -         5,825,389         5,858,045
   Management fees to affiliate (Note 7)          806,193           746,730         1,612,386           916,547         4,140,016
   Other general and administrative
      expenses                                    118,928               661           205,109             5,661           406,128
                                             ------------      ------------      ------------      ------------      ------------
     Total expenses                            16,283,736         2,879,285        22,097,912         6,747,597        31,204,625
                                             ------------      ------------      ------------      ------------      ------------
     Loss from operations                     (16,283,736)       (2,879,285)      (22,097,912)       (6,747,597)      (31,204,625)

Other income
   Interest income                                923,481           432,969         1,772,511           432,969         3,851,965
                                             ------------      ------------      ------------      ------------      ------------
     Net loss                                 (15,360,255)       (2,446,316)      (20,325,401)       (6,314,628)      (27,352,660)

Other comprehensive (loss) income
   Unrealized (loss) on
        marketable securities                      (2,482)                -           (45,058)                -                 -
                                             ------------      ------------      ------------      ------------      ------------
     Total comprehensive loss                $(15,362,737)     $ (2,446,316)     $(20,370,459)     $ (6,314,628)     $(27,352,660)
                                             ============      ============      ============      ============      ============
     Manager - Net loss                      $   (277,687)     $   (107,779)     $   (446,965)     $   (134,002)     $   (839,670)

     Shareholders - Net loss                 $(15,082,568)     $ (2,338,537)     $(19,878,436)     $ (6,180,626)     $(26,512,990)
     Net loss per share                      $    (17,323)     $     (2,686)     $    (22,832)     $     (7,099)     $    (30,452)
</TABLE>


              The accompanying notes are an integral part of these
                        condensed financial statements.


                                       4

<PAGE>


                          RIDGEWOOD ENERGY O FUND, LLC
                        (An exploratory stage enterprise)
                       CONDENSED STATEMENTS OF CASH FLOWS
                                   (Unaudited)

<TABLE>
<CAPTION>
                                                                                                    For the period
                                                                                                     December 21,
                                                                        Six months ended            2004 (inception)
                                                                            June 30,                    through
                                                                     2006              2005          June 30, 2006
                                                                     ----              ----          -------------
<S>                                                            <C>                <C>                <C>
Cash flows from operating activities
   Net loss                                                    $ (20,325,401)     $  (6,314,628)     $ (27,352,660)
   Adjustments to reconcile net loss to net cash (used in)
     provided by operating activities
     Dry-hole costs                                               20,280,417                  -         20,800,436
     Interest earned on marketable securities                     (1,405,065)                 -         (1,813,715)
     Interest earned on salvage fund                                 (21,285)                 -            (34,907)
     Changes in assets and liabilities
       Decrease in interest receivable                                 2,455                  -                  -
       Decrease (increase) in prepaid expenses                        34,258                  -            (21,699)
       Increase in accrued expenses payable                          314,627                  -            382,727
       (Decrease) increase in due to affiliates                      (10,043)           370,925              2,270
                                                               -------------      -------------      -------------
       Net cash used in operating activities                      (1,130,037)        (5,943,703)        (8,037,548)
                                                               -------------      -------------      -------------
Cash flows from investing activities
   Payments to operators for working interests and                         -                  -         (9,957,118)
      expenditures
   Capital expenditures for oil and gas properties                (5,096,112)                 -        (19,415,765)
   Funding of salvage fund                                                 -                  -         (1,000,000)
   Proceeds from the maturity of marketable securities            75,000,000                  -         75,000,000
   Investment in marketable securities                           (39,999,884)                 -       (113,460,926)
                                                               -------------      -------------      -------------
       Net cash provided by (used in) investing activities        29,904,004                  -        (68,833,809)
                                                               -------------      -------------      -------------
Cash flows from financing activities
   Contributions from shareholders                                         -        128,251,903        128,989,688
   Syndication costs paid                                            (19,500)       (13,981,506)       (14,739,674)
   Subscription receivable                                                 -         (1,762,260)                 -
                                                               -------------      -------------      -------------
       Net cash (used in) provided by financing activities           (19,500)       112,508,137        114,250,014
                                                               -------------      -------------      -------------
       Net increase in cash and cash equivalents                  28,754,467        106,564,434         37,378,657

       Cash and cash equivalents, beginning of period              8,624,190                  -                  -
                                                               -------------      -------------      -------------
       Cash and cash equivalents, end of period                $  37,378,657      $ 106,564,434      $  37,378,657
                                                               =============      =============      =============

Supplemental schedule of noncash investing activities
       Advances used for capital expenditures in oil
          and gas properties reclassified to unproved
          properties                                           $   9,957,118      $           -      $   9,957,118
                                                               =============      =============      =============
</TABLE>


              The accompanying notes are an integral part of these
                        condensed financial statements.


                                       5

<PAGE>


                          RIDGEWOOD ENERGY O FUND, LLC
                        (An exploratory stage enterprise)
                NOTES TO UNAUDITED CONDENSED FINANCIAL STATEMENTS

1.   Organization and Purpose

The Ridgewood Energy O Fund, LLC ("Fund"), a Delaware limited liability company,
was formed on December 21, 2004 and operates pursuant to a limited liability
company agreement ("Agreement") dated as of February 16, 2005 by and among
Ridgewood Energy Corporation ("Manager") and the shareholders of the Fund.
Although the date of formation is December 21, 2004, the Fund did not begin
operations until February 16, 2005 when it began its private offering of shares.
There were no business activities prior to February 16, 2005.

The Fund was organized to acquire, drill, construct and develop oil and natural
gas properties located in the United States offshore waters of Texas, Louisiana,
and Alabama in the Gulf of Mexico. The Fund has devoted most of its efforts to
raising capital and oil and natural gas exploration activities. To date, the
Fund has not earned revenue from these operations and is considered in the
exploratory stage.

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 outside custodians,
depositories, accountants, attorneys, broker-dealers, corporate fiduciaries,
insurers, banks and others as required (Notes 2, 6 and 7).

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, 2005 included in the Fund's Annual
Report Amendment No. 1 on Form 10/A ("Form 10/A").



                                       6
<PAGE>

     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, impairment allowances, and
environmental liabilities. Actual results may differ from those estimates.

     Advances to Operators for Working Interests and Expenditures

Each participation agreement that the Fund executes for an exploratory project
requires the Fund to make a payment to the working interest owner for the Fund's
ownership rights and working interest in the project. The Fund will account for
such payments as advances to operators for working interests and expenditures.
As drilling costs are incurred the payments are capitalized as unproved
properties.

     Oil and natural gas properties

Investments in oil and natural 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 natural gas producing
activities is followed. Acquisition costs are capitalized when incurred. Other
oil and natural 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 natural crude oil
and natural 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 (i.e. a producing well), 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 or retirement is
recognized, taking into consideration the amount of any recorded impairment if
the property had been assessed for impairment. It is not the Manager's intention
to sell any of the Fund's property interests.

Capitalized acquisition costs of producing oil and natural gas properties after
recognizing estimated salvage values are depleted by the unit-of-production
method.



                                       7
<PAGE>

     Revenue Recognition

Oil and natural gas sales are recognized when delivery is made by the Operator
to the purchaser and title is transferred (i.e., production has been delivered
to a pipeline or transport vehicle). The Fund has not earned revenue from
inception to date.

The volume of oil and natural gas sold on the Fund's behalf may differ from the
volume of oil and natural gas the Fund is entitled to. The Fund will account for
such oil and natural gas production imbalances by the entitlements method. Under
the entitlements method, the Fund will recognize a receivable from other working
interest owners for volumes oversold by other working interest owners, and a
payable to other working interest owners for volumes oversold by the Fund. As of
June 30, 2006 and for the period December 21, 2004 (Inception) through June
30,2006, there were no oil or natural gas balancing arrangements between the
Fund and other working interest owners.

     Interest Income

Interest income is recognized when earned.

     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 outside brokers are reflected as a reduction of
shareholders' capital.

     Asset Retirement Obligations

For oil and natural gas properties, there are obligations to perform removal and
remediation activities when the properties are retired. The Financial Accounting
Standards Board ("FASB") issued Statement of Financial Accounting Standards
("SFAS") No. 143, "Accounting for Asset Retirement Obligations" ("SFAS No.
143"), effective for years beginning after December 15, 2002. SFAS No. 143
requires the Fund to record a separate liability for the discounted present
value of the Fund's asset retirement obligations, with an offsetting increase to
the related oil and natural gas properties on the balance sheet. 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 projects are expensed as incurred as dry-hole costs.

                                          June 30, 2006  December 31, 2005
                                          -------------  -----------------
          Balance - Beginning of period     $       -        $       -

          Liabilities incurred                233,938                -
          Liabilities settled                (233,938)               -
                                            ---------        ---------
          Balance - End of period           $       -        $       -
                                            =========        =========

In March 2005, the FASB issued FASB Interpretation ("FIN") No. 47, "Accounting
for Conditional Asset Retirement Obligations" ("FIN 47"). This interpretation
clarifies that the term "conditional asset retirement obligation" as used in
SFAS No. 143 refers to a legal obligation to perform an asset retirement
activity in which the timing and/or method of settlement are conditional on a
future event that may or may not be within the control of the entity incurring


                                       8
<PAGE>

the obligation. The obligation to perform the asset retirement activity is
unconditional even though uncertainty exists about the timing and/or method of
settlement. Thus, the timing and/or method of settlement may be conditional on a
future event. Accordingly, an entity is required to recognize a liability for
the fair value of a conditional asset retirement obligation if the fair value of
the liability can be reasonably estimated. Uncertainty about the timing and/or
method of settlement of a conditional asset retirement obligation should be
factored into the measurement of the liability, rather than the timing of
recognition of the liability, when sufficient information exists. FIN 47 was
effective for calendar year-end entities no later than December 31, 2005. The
application of FIN 47 did not have an impact on the Fund's financial position or
results of operations.

     Impairment of Long-Lived Assets

In accordance with the provisions of SFAS No. 144, "Accounting for the
Impairment of Long-Lived Assets" ("SFAS No. 144"), long-lived assets, such as
oil and natural gas properties, are evaluated when events or changes in
circumstances indicate that 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. As of
June 30, 2006 and December 31, 2005, no impairments were recorded.

     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 and platform and pipeline costs.
As of June 30, 2006 and December 31, 2005, the Fund did not have proved oil and
natural gas reserves.

     Income Taxes

No provision is made for income taxes in the financial statements as the income
or losses are passed through and included in the tax returns of the individual
shareholders.

     Cash and cash equivalents / Salvage fund

All highly liquid investments with maturities when purchased of three months or
less are considered as cash and cash equivalents. At times, bank deposits may be
in excess of federal insured limits. As of June 30, 2006 and December 31, 2005,
bank balances inclusive of the salvage fund exceeded federally insured limits by
approximately $3 million and $9.4 million, respectively. The Fund maintains bank
deposits with accredited financial institutions to mitigate such risk. As of
both June 30, 2006 and December 31, 2005, cash and cash equivalents of
approximately $35.2 million and nil, respectively, are investments in three
month US Treasury Notes.



                                       9
<PAGE>

Income and Expense Allocation

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

3.   Recent Accounting Pronouncements

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 is effective for financial statements issued for fiscal years beginning
after November 15, 2007. The Fund does not expect this guidance to have a
material impact on the financial statements.

In May 2005, the FASB issued SFAS No. 154, "Accounting Changes and Error
Corrections - a replacement of APB Opinion No. 20 and FASB Statement No. 3"
("SFAS No. 154"). SFAS No. 154 requires, unless impracticable, retrospective
application to prior periods' financial statements of changes in accounting
principle where transition is not specified by a new accounting pronouncement.
SFAS No. 154 also requires that retrospective application of a change in
accounting principle be limited to the direct effects of the change. Indirect
effects of a change in accounting principle should be recognized in the period
of the accounting change. SFAS No. 154 was effective for accounting changes and
corrections of errors made in fiscal years beginning after December 15, 2005.
The adoption of SFAS No. 154 had no impact on the financial statements.

In January 2003, the FASB issued FIN No. 46, "Consolidation of Variable Interest
Entities", ("FIN 46") which changes the criteria by which one company includes
another entity in its consolidated financial statements. FIN 46 requires a
variable interest entity to be consolidated by a company if that company is
subject to a majority of the risk of loss from the variable interest entity's
activities or entitled to receive a majority of the entity's residual returns or
both. The consolidation requirements of FIN 46 apply immediately to variable
interest entities created after December 31, 2003, and apply in the first fiscal
period ending after March 15, 2004, for variable interest entities created prior
to January 1, 2004. In December 2003, the FASB issued a revision of FIN 46 ("FIN
46R") to clarify some of the provisions and to exempt certain entities from its
requirements. The Fund has applied the provisions of FIN 46R effective December
21, 2004, with no impact on the financial statements.

FASB Staff Position ("FSP") 115-1 and 124-1, the Meaning of Other Than Temporary
Impairment and its Application to Certain Investments ("FSP 115-1 and 124-1").
This FSP addresses the determination as to when an investment is considered
impaired, whether that impairment is other than temporary and the measurement of


                                       10
<PAGE>

the impairment loss. It also requires certain disclosures about unrealized
losses that have not been recognized as other than temporary impairments. This
guidance applies to equity securities that have a readily determinable fair
value and all debt securities. It does not apply to investments accounted for
under the equity method. An investment is impaired if its fair value is less
than its cost, as assessed at the individual security level. When an investment
is impaired, the investor is required to evaluate whether the impairment is
other than temporary. If other than temporary, the unrealized loss must be
recognized. For all investments in an unrealized loss position for which other
than temporary impairments have not been recognized, the investor should
disclose by category of investment the amount of unrealized losses and the fair
value of investments with unrealized losses and related narrative disclosures.
FSP 115-1 and 124-1 was effective for reporting periods beginning after December
15, 2005. The adoption of FSP 115-1 and 124-1 had no impact on the financial
statements.

4.   Unproved Properties - Capitalized Exploratory Well Costs

In April 2005, FASB issued FSP 19-1, "Accounting for Suspended Well Costs",
("FSP 19-1"). This FSP was issued to address whether there were circumstances
that would permit the continued capitalization of exploratory well costs beyond
one year, other than when further exploratory drilling is planned and major
capital expenditures would be required to develop the project. FSP 19-1 requires
the continued capitalization of suspended well costs if the well has found a
sufficient quantity of reserves to justify its completion as a producing well
and the entity is making sufficient progress assessing these reserves and the
economic and operating viability of the project. All relevant facts and
circumstances should be evaluated in determining whether an entity is making
sufficient progress assessing the reserves and FSP 19-1 provides several
indicators in this evaluation. FSP 19-1 prohibits continued capitalization of
suspended well costs on the chance that market conditions will change or
technology will be developed to make the project economic.

The Fund adopted FSP 19-1 during the first quarter of 2005. 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 assessing the reserves. Capitalization 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. For the three and six months ended June
30, 2006 dry-hole costs were approximately $15.4 million and $20.3 million,
respectively. There were no dry-hole costs for the three and six months ended
June 30, 2005. For the period December 21, 2004 (Inception) through June 30,
2006 dry-hole costs were approximately $20.8 million.

The following table reflects the net changes in unproved properties for the six
months ended June 30, 2006 and for the year ended December 31, 2005. As of June
30, 2006 and December 31, 2005, the Fund had no capitalized exploratory well
costs greater than one year.



                                       11
<PAGE>


                                              For the
                                             Six months         For the year
                                                ended              ended
                                            June 30, 2006     December 31, 2005
                                            -------------     -----------------
          Balance - beginning of period      $16,873,053        $         -

          Additions to capitalized
            exploratory well costs
            pending the determination
            of proved reserves                 3,936,801         16,873,053
                                             -----------        -----------

          Balance - end of period            $20,809,854        $16,873,053
                                             ===========        ===========


5. Short-term Investments in Marketable Securities inclusive of Salvage Fund

Short-term investments are comprised of US Treasury Notes with maturities
greater than six months and are considered held-to-maturity investments.
Held-to-maturity securities are those investments that the Fund has the ability
and intent to hold until maturity. Held to maturity investments are recorded at
cost plus accrued income, adjusted for the amortization of premiums and
discounts, which approximate market value. Interest income is accrued as earned.
Held to maturity investments as of June 30, 2006 will mature in November 2006.

Available for sale securities are carried in the financial statements at fair
value. The Fund had no short-term investments considered available for sale as
of June 30, 2006. Available for sale investments as of December 31, 2005 matured
in May 2006. The following table is a summary of short-term investments
considered available for sale as of December 31, 2005.

                                  As of December 31, 2005
                              -------------------------------

                                                   Fair
                                   Cost           Value
                              --------------- ---------------
Available-for-Sale

    U.S. Treasury Notes         $73,869,692     $73,914,750


6.   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 Operating Agreement, is to be distributed. Such distribution will be
allocated 85% to the shareholders and 15% to the Manager, as defined in the
Fund's Operating Agreement.

Available Cash from Dispositions, as defined in the Fund's Operating 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 have been no distributions made by the Fund.



                                       12
<PAGE>

7.   Related Parties

Ridgewood Energy Corporation, the Manager, was paid a one time investment fee of
4.5% of initial capital contributions. Fees are payable for services of
investigating and evaluating investment opportunities and effecting transactions
when the capital contribution is made. For both the six months ended June 30,
2005 and the period December 21, 2004 (Inception) through June 30, 2006,
investment fees were approximately $5.9 million. Of this amount approximately $2
thousand and $16 thousand were included in due to affiliates as of June 30, 2006
and December 31, 2005, respectively. In 2006, there were no investment fees.

A management agreement provides that the Manager render management,
administrative and advisory services. For such services, the Manager receives an
annual management fee, payable monthly, of 2.5% of total capital contributions.
Management fees of approximately $0.8 million and $1.6 million were incurred and
paid for the three months ended June 30, 2006 and for the six months ended June
30, 2006, respectively. For the three and six months ended June 30, 2005,
management fees of approximately $0.7 million and $0.9 million, respectively,
were incurred and paid. Management fees of approximately $4.1 million were
incurred and paid for the period from December 21, 2004 (Inception) through June
30, 2006.

The Manager was paid an offering fee which approximated 3.5% of capital
contributions to cover expenses incurred in the offer and sale of shares of the
Fund. Such offering fee was included in syndication costs (Note 2) of
approximately $14.7 million. For both the six months ended June 30, 2005 and the
period December 21, 2004 (Inception) through June 30, 2006, offering fees were
approximately $4.6 million. Of this amount approximately $2 thousand and $12
thousand, respectively, were included in due to affiliates as of June 30, 2006
and December 31, 2005.

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. As of June 30, 2006 and December 31, 2005, the Manager owed the Fund
nil and approximately $3 thousand for the overpayment of fees, which is included
in due to affiliates.

In 2005, Ridgewood Securities Corporation, a registered broker-dealer affiliated
with the Manager, was paid selling commissions and placement fees of
approximately $0.3 million and $1.3 million, respectively, for shares of the
Fund sold which are reflected in syndication costs (Note 2). As of June 30, 2006
and December 31, 2005, approximately five hundred dollars and $4 thousand
respectively, were included in due to affiliates.

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.



                                       13
<PAGE>


8.   Fair Value of Financial Instruments

As of June 30, 2006 and for the year ended December 31, 2005, the carrying value
of cash and cash equivalents, short-term investments in marketable securities,
and salvage fund approximate fair value. Cash and cash equivalents principally
consist of money market funds and short-term investments in three month US
Treasury Notes.

9.   Commitment and Contingencies

     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 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. As of June 30, 2006 and December 31, 2005,
there were no known environmental contingencies that required the Fund to record
a liability.

     Salvage Fund

Pursuant to the Fund's Operating 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.

Interest earned on the account will become part of the salvage fund; there are
no legal restrictions on the withdrawal of the salvage fund.

     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.

On May 22, 2006 the Fund reported a claim to its insurance carrier for cost
recovery of sidetrack operations related to the West Cameron 78/95 project.
Subsequent to the sidetrack operations the project was determined to be a
dry-hole. Through June 30, 2006 the Fund recorded dry-hole costs of
approximately $7.5 million excluding any insurance recovery amounts. Insurance
recovery proceeds will be recognized in a future period when reasonably
estimable and assured.


                                       14
<PAGE>

     Hurricane Damage

During Hurricane Katrina, the West Delta 95 project sustained storm damage.
During April 2006 recovery operations began with the removal of a bent section
of the drill pipe, the installation of a structural support device and a new
section of pipe so that drilling can resume. This phase of the recovery
operation was successfully completed. Recovery operations were temporarily
suspended in July 2006 due to the hurricane season. The Fund's portion of
recovery costs through July 2006 approximated $8.4 million based on its promoted
working interest. Through June 30, 2006 approximately $7.1 million of recovery
costs were incurred and recorded in unproved properties on the Fund's balance
sheet.

The final phase of the recovery operation is anticipated to begin during the
fourth quarter of 2006. Although the Operator anticipates a successful recovery,
there is the risk that this may not be accomplished. Based on current estimates
the Fund's portion of the costs to be incurred for the final recovery stage is
approximately $2.9 million.

The Fund has informed its insurance carrier of its intention to file a claim to
be reimbursed for the West Delta 95 project recovery costs. If the recovery plan
is not successful, the Operator and other working interest owners will determine
if the well will be re-drilled. Current estimates of the total costs associated
with a re-drill of the well are approximately $37 million. The Fund believes
that should a re-drill occur, some, but not all, of its pro rata portion of the
re-drill costs will be covered by insurance, although it is not possible at this
time to make an estimate of what may or may not be covered.

Due to the uncertainty surrounding the recovery operation, the Fund can not make
a reasonable estimate of any expected insurance recovery. As such, no insurance
recovery, related to the West Delta 95 recovery costs has been reflected in the
accompanying financial statements.

10.   Subsequent Events

On July 17, 2006 the Fund acquired a 16.67% working interest in the South Pelto
9 project from the Operator, Newfield Exploration Company ("Newfield"). This is
a one well project with a target depth of 17,700 feet. This well began drilling
September 26, 2006.


                                       15
<PAGE>


Item 2. Management's Discussion and Analysis of Financial Condition and Results
of Operations

Cautionary Statement Regarding Forward-Looking Statements

This Quarterly Report on Form 10-Q, including all documents incorporated by
reference, includes "forward-looking" statements within the meaning of Section
27A of the Securities Act of 1933, as amended (the "Securities Act") and Section
21E of the Securities Exchange Act of 1934, as amended, and the Private
Securities Litigation Reform Act of 1995, and the "safe harbor" provisions
thereof. These forward-looking statements are usually accompanied by the words
"anticipates," "believes," "plan," "seek," "expects," "intends," "estimates,"
"projects," "will likely result," "will continue," "future" and similar terms
and expressions. The forward-looking statements in this Quarterly Report on Form
10-Q reflect our current views with respect to future events and financial
performance. These forward-looking statements are subject to certain risks and
uncertainties, including, among other things, the high-risk nature of natural
gas exploratory operations, the fact that our drilling activities are managed by
third parties, the volatility of natural gas prices and extraction, and those
other risks and uncertainties discussed in the Fund's Annual Report Amendment
No.1 on Form 10/A ("Form 10/A") filed with the Securities and Exchange
Commission that could cause actual results to differ materially from historical
results or those anticipated. In light of these risks and uncertainties, there
can be no assurance that the forward-looking information contained in this
Quarterly Report on Form 10-Q will in fact occur or prove to be accurate.
Readers should not place undue reliance on the forward-looking statements
contained herein, which speak only as of today's date. We undertake no
obligation to publicly revise these forward-looking statements to reflect events
or circumstances that may arise after today. All subsequent written or oral
forward-looking statements attributable to us or persons acting on our behalf
are expressly qualified in their entirety by this section.

Critical Accounting Policies and Estimates

The following discussion and analysis of our financial condition and operating
results is based on our financial statements. The preparation of this Quarterly
Report on Form 10-Q requires us to make estimates and assumptions that affect
the reported amount of assets and liabilities, disclosure of contingent assets
and liabilities at the date of our 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 on Form 10-Q for a
presentation of the Fund's critical accounting principles. No changes have been
made to our critical accounting policies and estimates since the filing of the
Form 10/A.

Overview

The Fund is an independent oil and natural gas producer. Our primary investment
objective is to generate cash flow for distribution to its shareholders through
participation in oil and natural gas exploration and development projects in the
Gulf of Mexico. The Fund does not directly explore for, or operate, any
projects. The Fund began its operations by offering our shares in a private
offering on February 16, 2005. As a result of such offering, we raised
approximately $129.0 million through the sale of 870.6486 shares of LLC


                                       16
<PAGE>

membership interests. After the payment of approximately $20.6 million in
offering fees, commissions and investment fees to Ridgewood Energy Corporation,
affiliates and broker-dealers, the Fund retained approximately $108.4 million
available for investment. Investment fees represent a one time fee of 4.5% of
initial capital contributions. The fee is payable for the service of
investigating and evaluating investment opportunities and affecting
transactions.

The Manager performs certain duties on the Fund's behalf including the
evaluation of potential projects for investment and ongoing administrative and
advisory services associated with these projects. 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 for the
management of all exploration, development and producing operations, as
appropriate. As compensation for the above duties, the Manager is paid a
one-time investment fee (4.5%) for the evaluation of projects on the Fund's
behalf and an annual management fee (2.5%) payable monthly, for ongoing
administrative and advisory duties as well as reimbursement of expenses. The
Manager also participates in distributions as additional compensation for its
administrative and management services

Project Update

The Fund owns working interests in five offshore blocks and has participated in
the drilling of five wells, of which one is in process, three were determined to
be dry-holes as of March 20, 2006, May 22, 2006 and July 6, 2006 respectively,
and one which began drilling September 26, 2006.

West Delta 95

The Fund acquired a 20% working interest in West Delta 95 from GOM Shelf LLC
(Apache Corporation) ("Apache") and an 8.05% working interest from BP American
Production Co. ("BP"), the Operator. In consideration of this interest the Fund
paid a promote to Apache totaling approximately $3.1 million, on the first $25.4
million of drilling costs. The Fund is paying an 8.05% promote (two for one) to
BP on the total drilling costs for the first well. Through June 30, 2006, the
Fund has paid BP approximately $3.4 million in consideration for its interest.
On May 11, 2005 the first well began drilling and if successful, it is likely
that there will be five development wells to follow.

In August 2005, before reaching its target depth, the project was evacuated in
preparation for Hurricane Katrina. The Mineral Management Services ("MMS")
mandates that a storm packer or cement plug be utilized before evacuating a well
prior to a storm. Generally, a storm packer's purpose is to isolate pressure
below the packer, which is located below the mud line, from sections above the
packer so the well is secure. In accordance with MMS regulations, the Operator
set the storm packer in the well and evacuated the rig. Prior to Hurricane
Katrina, an estimated $31.1 million of drilling costs had been incurred by the
Operator, of which the Funds' portion was approximately $14.3 million.
Notwithstanding the storm packer, as a result of Hurricane Katrina the well
sustained damage to the conductor/drive pipe which was bent and partially buried
in the Gulf floor.



                                       17
<PAGE>


On April 15, 2006, recovery operations began to remove the drive pipe from the
Gulf floor. The lateral section of the well bore was cut and removed in several
sections. A structural device called a coffer dam was placed around the vertical
stub of the well bore to prevent sediment and other excavated materials from
falling back into the area. Having cut and removed the bent pipe, divers
prepared the remaining vertical pipe to be coupled with new pipe to replace the
portion that was bent over in the hurricane.

Recovery operations were suspended in July 2006 and drilling will not resume
until subsequent to the 2006 hurricane season. Through July 2006, approximately
$23.3 million has been incurred by all working interest owners since Hurricane
Katrina. The Fund's estimated portion of costs incurred through July 2006 is
approximately $8.4 million.

The final stages of the recovery operation are expected to begin during the
first quarter of 2007 based upon the availability of a drilling rig. The
drilling rig will drive a new caisson, a reinforcing support pipe, around the
repaired pipe into the Gulf floor approximately 300 feet below the mud line and
will extend up to the rig base. Once accomplished, the Operator will remove the
coffer dam which will allow natural currents to fill in mud around the new
caisson. The final step will be to remove the storm packer opening up the well
so that drilling can resume. Although the Operator anticipates a successful
recovery, there is still a possibility this may not be accomplished in which
case the Operator would have to plug and abandon the well and determine if the
well is to be re-drilled. The Fund's portion of the costs to be incurred for the
final recovery stage is anticipated to be approximately $2.9 million assuming
the storm packer is removed 27 days after the rig is on location and the total
depth is reached 30 days after pulling the storm packer.

The Fund has notified its insurance carrier of its intention to file a claim for
the costs of recovering the West Delta 95 well. If the recovery plan is not
successful, the operator and other working interest owners will determine if the
well will be re-drilled. Current estimates of the total costs associated with a
re-drill of the well are $37 million. The Fund believes that should a re-drill
occur, some, but not all, of its pro rata portion of the re-drill costs will be
covered by insurance. It is not possible at this time to make an estimate of
what insurance may cover.

Eugene Island 357

The Fund acquired an 18% working interest from Newfield Exploration Company
("Newfield"), the Operator. In consideration of this interest, the Fund paid a
promote of 1.32 to 1 on total drilling costs. The well had two targets; one at
14,500 feet and one at 15,500 feet and if successful, there was a smaller third
target at 16,500 feet which was the planned total depth of the well.

The well began drilling on January 10, 2006. Newfield encountered problems from
the beginning with lost circulation problems and rig repairs. Evaluation of the
well at both 14,500 feet and 15,500 feet indicated both zones contained sands
with salt water and not hydrocarbons. On March 20, 2006 the decision was made to
plug and abandon the well. Dry-hole costs including plug and abandonment
expenses incurred by the Fund for the six months ended June 30, 2006, for six
months ended June 30, 2005, and for the period December 21, 2004 (Inception)
through June 30, 2006 were approximately $4.1 million, nil and $4.4 million,
respectively.



                                       18
<PAGE>

Eugene Island 334

The Fund acquired a 33.33% working interest from the Operator, Devon Energy
Production ("Devon"). In consideration of this interest the Fund paid a promote
of 1.33 to 1 on the total drilling costs. This is a one well project with a
target depth of 17,000 feet. The well began drilling on March 25, 2006. On May
22, 2006 the decision was made to plug and abandon the well. Dry-hole costs
including plug and abandonment expense incurred by the Fund for the three months
ended June 30, 2006, for the six months ended June 30, 2006, and for the period
December 21, 2004 (Inception) through June 30, 2006 were approximately $4.6
million, $8.7 million and $8.9 million, respectively.

West Cameron 78/95

The Fund acquired a 30% working interest from the Operator, El Paso. In
consideration of this interest the Fund paid a promote totaling approximately
$1.5 million of the first $6.0 million of drilling costs. This was a one well
project with a target depth of 14,500 feet. The well began drilling on April 21,
2006. Drilling went according to plan until the well reached a depth of 10,781
feet on May 17, 2006 when the drill string became stuck. The smaller drill pipe
was recovered and the well was sidetracked (re-drilled) at a depth of 4,880
feet. On May 22, 2006 the Fund reported a claim to its insurance carrier for
cost recovery of approximately $1.8 million for the sidetrack operations.
Drilling continued to 14,500 feet and at which point electric logs were inserted
into the pipe to detect the presence of hydrocarbons. Based on the results of
the electric log assessment the well was determined to be a dry-hole. On July 6,
2006 the decision was made to plug and abandon the well. Dry-hole costs incurred
by the Fund for the three months ended June 30, 2006, for the six months ended
June 30, 2006, and for the period from December 21, 2004 (Inception) through
June 30, 2006 totaled approximately $7.5 million, $7.5 million and $7.5 million,
respectively, excluding any insurance recovery amounts. Total estimated dry-hole
costs are approximately $7.8 million, including plug and abandonment charges,
excluding any insurance recovery amounts. Insurance recovery proceeds, if any,
will be recorded in future periods when reasonably assured and estimable.

South Pelto 9

On July 17, 2006, the Fund acquired a 16.67% working interest in the South
Pelto 9 project. This is a one well project located offshore Louisianna. The
well began drilling on September 26, 2006.

Results of Operations

For the six months ended June 30, 2006, the six months ended June 30, 2005, and
for the period December 21, 2004 (Inception) through June 30, 2006, the Fund had
operating losses of approximately $22.1 million, $6.7 million and $31.3 million,
respectively. Losses for the three months ended June 30, 2006 are primarily a
result of dry-hole costs of approximately $15.4 million. Inception to date
operating losses of approximately $31.3 million are comprised of the onetime
investment fee paid to the Manager of approximately $5.9 million, dry-hole costs
of approximately $20.8 million, annual management fees of approximately $4.1
million and other general and administrative expenses totaling approximately
$0.5 million.

The Manager is paid a one time investment fee of 4.5% of initial capital
contributions. The fee is payable for the service of investigating and
evaluating investment opportunities and affecting transactions when the capital
contributions are made. For the three and six months ended June 30, 2005,
investment fees paid were approximately $2.1 million and $5.8 million,
respectively. There were no investment fees incurred or paid during 2006 as the
Fund was closed as of December 31, 2005.


                                       19
<PAGE>

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. Dry-hole costs,
inclusive of plug and abandonment costs, are recognized in the period in which
the costs are incurred. For the three and six months ended June 30, 2006, and
for the period December 21, 2004 (Inception) through June 30, 2006 dry-hole
costs were approximately $15.4 million, $20.3 million, and $20.8 million,
respectively. There were no dry-hole costs for the three and six months ended
June 30, 2005 as the Fund was not participating in projects at that time.

The Manager receives annual management fee, payable monthly, of 2.5% of total
capital contributions. 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. For the three months ended June 30, 2006, the six months
ended June 30, 2006, and for the period December 21, 2004 (Inception) through
June 30, 2006 management fees of approximately $0.8 million, $1.6 million and
$4.1 million were incurred and paid. Management fees of approximately $0.7
million and $0.9 million, respectively, were incurred and paid for the three and
six months ended June 30, 2005.

Other general and administrative expenses represent accounting, legal, fiduciary
fees and insurance expenses specifically identifiable or allocable to the Fund.
Accounting and legal fees represent annual audit and tax preparation fees,
quarterly reviews and filing fees of the Fund. Fiduciary fees represent bank
fees associated with the management of the Fund's short-term investment
portfolio in US Treasury Notes and have increase in 2006 due to greater
investment activity. Insurance expense represents premiums related to well
control insurance and directors and officers liability policy and are allocated
to the Fund based on capital raised by all oil and natural gas funds managed by
the Manager. General and administrative expenses of approximately $0.1 million,
$0.2 million and $0.3 million were incurred and paid for the three months ended
June 30, 2006, the six months ended June 30, 2006 and for the period December
21, 2004 (Inception) through June 30, 2006, respectively. General and
administrative expenses of approximately $7 hundred dollars and $6 thousand
dollars were incurred and paid for the three months and six months ended June
30, 2005, respectively.

Other Income

Other income is comprised solely of interest income and represents interest
earned on money market accounts and short-term US Treasury Notes. For the three
months ended June 30, 2006, for the six months ended June 30, 2006 and for the
period December 21, 2004 (Inception) through June 30, 2006 other income totaled
approximately $0.9 million, $1.8 million and $3.9 million. In 2006 the average
monthly interest income increased as a result of higher interest rates in 2006
compared to 2005.


                                       20
<PAGE>

Other Comprehensive (Loss) Income

Other comprehensive (loss) income is comprised solely of the unrealized gains or
losses on short-term investments. For the three and six months ended June 30,
2006 unrealized losses were approximately $2 thousand and $45 thousand,
respectively. The unrealized loss for the six months ended June 30, 2006
resulted from the reversal of unrealized holding gains recorded on short-term
investments which matured during the period. There are no short term investments
classified as available for sale at June 30, 2006.

Capital Resources and Liquidity

Cash and cash equivalents increased by $28.8 million during the first six months
of 2006 from $8.6 million at December 31, 2005 to $37.4 million at June 30,
2006. In addition to cash and cash equivalents, the Fund had $40.3 million of
available capital invested in six month US Treasury Notes at June 30, 2006. The
increase in cash and cash equivalents is a result of an investment of
approximately $35.2 million from short-term US Treasury Notes classified as cash
equivalents partially offset by capital expenditures relating to oil and natural
gas properties of approximately $5.1 million and the net payment of operating
and financing expenses offset by interest earned totaling $1.3 million.

Operating cash used for the period December 21, 2004 (Inception) through June
30, 2006 of approximately $8.1 million relates primarily to investment and
management fees paid to the Manager approximating $10.0 million partially offset
by the interest income received in money market funds and short term
investments. Cash used in operating activities for the six months ended June 30,
2006 was attributable primarily to the payment of management fees and various
general and administrative expenses partially offset by interest received on
money market funds and short-term investments.

Net cash used in investing activities for the period December 21, 2004
(Inception) through June 30, 2006 included approximately $19.4 million used for
capital expenditures and approximately $9.9 million which the Fund advanced to
operators for working interests and expenditures to be utilized for 2006
exploration and development activities. The remaining capital of approximately
$113.5 million has been placed in short-term US Treasury Notes until such time
that cash is needed for future oil and natural gas investment purposes. Net cash
used in investing activities for the six months ended June 30, 2006 of
approximately $5.1 million related to the West Delta 95, Eugene Island 334,
Eugene Island 357 and West Cameron 78/95 projects.

Net cash provided by financing activities for the period December 21, 2004
(Inception) through June 30, 2006 represents approximately $114.3 million net
proceeds from the sale of shares of the Fund, which was comprised of
approximately $129.0 million shareholder contributions less syndication costs
totaling approximately $14.7 million. Net cash used in financing activities for
the six months ended June 30, 2006 of approximately $20 thousand represents the
payment of syndication costs.

The Manager may distribute available cash from operations which includes cash
received by the Fund from producing wells (not including cash flow from
dispositions and investor capital contributions), less operating expenses and
other cash expenditures and less reserves for operating expenses, plugging and
abandonment costs and certain other actual and contingent liabilities. No
distributions have been made from inception through June 30, 2006.



                                       21
<PAGE>

We expect to meet our cash commitments for the next twelve months from our cash
and investments on hand.

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, 2006, such estimated
capital expenditures to be spent total approximately $51.9 million, all of which
is expected to be paid out of unspent capital contributions within the following
12 months.

After consideration of the identified projects as well as projected fund
expenses and salvage fund requirements, the Fund is projecting remaining cash
reserves to be utilized for future projects of approximately $20.6 million.

The table below presents exploration and development capital expenditures from
inception as well as estimated budgeted amounts for future periods:



                                       22
<PAGE>

<TABLE>
<CAPTION>
Estimated Capital Expenditures
As of June 30, 2006                         Total Project         Spent Through         To be Spent
($ Millions)                                    Costs             June 30, 2006       Next 12 Months
                                         --------------------   ------------------   ------------------
<S>                                      <C>                    <C>                  <C>
Projects
        West Delta 95                                 $ 72.6               $ 20.8               $ 51.8
        Eugene Island 357 (i)                            4.4                  4.4                    -
        Eugene Island 334 (ii)                           8.9                  8.9                    -
        West Cameron 78/95 (iii)                         7.5                  7.5                    -
                                         --------------------   ------------------   ------------------
                                                      $ 93.4               $ 41.6               $ 51.8
                                         ====================   ==================   ==================
</TABLE>

     (i)Eugene Island 357 was determined to be a dry-hole in March 2006.
    (ii)Eugene Island 334 was determined to be a dry-hole in May 2006.
   (iii)West Cameron 78/95 was determined to be a dry-hole in July 2006.


On July 17, 2006, the Fund acquired a 16.67% working interest in South Pelto 9
from the Operator, Newfield. In consideration of this interest the Fund will pay
a promote of 1.4 to 1 totaling approximately $1.0 million on the first $3.7
million of drilling costs. This project is scheduled to begin drilling in
September 2006. This is a one well project with a target depth of 17,700 feet.
Total budgeted costs to the Fund are estimated to be $5.2 million.

Item 3.  Quantitative and Qualitative Disclosures about Market Risk

The principal market risks to which the Fund is exposed that may adversely
impact the Fund's results of operations and financial position are changes in
oil and natural gas prices. The Fund has no market risk sensitive instruments
held for trading purposes. Information about market risks for the six months
ended June 30, 2006, does not differ materially from that discussed under Item
2C of the Fund's 2005 Annual Report Amendment No. 1 Form 10/A ("Form 10/A")
filed with the SEC.

Item 4.  Controls and Procedures

(a)     Evaluation of Disclosure Controls and Procedures

The Fund maintains disclosure controls and procedures that are designed to
ensure that information required to be disclosed in the reports that the Fund
files or submits as defined in Rules 13a-15(e) of the Securities and Exchange
Act of 1934, as amended ("Exchange Act") is recorded, processed, summarized and
reported within the time periods specified in the SEC's rules and forms, and
that such information is accumulated and communicated to the Chief Executive
Officer ("CEO") and Chief Financial Officer ("CFO") to allow timely decisions
regarding required disclosures.

The Fund carried out the evaluation required by paragraph (b) of the Exchange
Act Rules 13a-15 and 15d-15, under the supervision and with the participation of
our management, including the CEO and CFO, of the effectiveness of our
"disclosure controls and procedures" (as defined in the Exchange Act Rules
13a-15(e) and 15d-15(e)). Based upon this evaluation, the CEO and CFO have
concluded that as of June 30, 2006 ("Evaluation Date"), our disclosure controls
and procedures were not effective as of the Evaluation Date because of the
material weaknesses described below.


                                       23
<PAGE>

Subsequent to the issuance of the Fund's Form 10 originally filed with the
Securities and Exchange Commission (the "SEC") on April 21, 2006, as reported
under Item 4.02 of the Form 8-K/A filed by the Fund on August 23, 2006, on
August 9, 2006, Ridgewood Energy Corporation (the "Manager") of the Fund
concluded that the Fund's financial statements as of and for the period from
December 21, 2004 (Inception) to December 31, 2005 as included in the Fund's
Form 10 should no longer be relied upon and should be restated to correct for
errors detected by Management. Therefore, the Fund filed Form 10/A on November
13, 2006.

(b)     Changes in Internal Control over Financial Reporting

In the course of our evaluation of disclosure controls and procedures,
management considered certain internal control areas in which we have made and
are continuing to make changes to improve and enhance controls. Based upon that
evaluation, the CEO and CFO concluded that there were no changes in our internal
control over financial reporting identified in connection with the evaluation
required by paragraph (d) of Exchange Act Rules 13a-15 or 15d-15 that occurred
during the Fund's most recent fiscal quarter, the quarter ended June 30, 2006
that have materially affected, or are reasonably likely to materially affect,
our internal controls over financial reporting.

As reported in Note 12 of the Fund's 2005 Form 10/A filed on November 13, 2006,
subsequent to the issuance of the Fund's financial statements as of and for the
year ended December 31, 2005, management identified accounting errors. These
accounting errors, which are the result of material weaknesses, also existed as
of June 30, 2006 and therefore are reported in this Form 10-Q.

(c)     Material Weaknesses

After examining certain transactions and reviewing various reconciliations from
2004 to 2005, various accounting errors were identified. Based upon management's
review, it has been determined these errors were inadvertent and unintentional.
As a result of these initial findings, on August 9, 2006, Management announced
the Fund would restate its previously filed financial statements. Management
expanded the scope of the review to include pre and post-closing procedures. As
a result of this expanded review, additional items were identified and
corrected. The effects of these restatements were previously reflected in our
Form 10/A as filed with the SEC on November 13, 2006.

Other accounting errors were identified as part of the Fund's review of various
other historical transactions. The Fund concluded the reason for these errors
primarily related to the lack of sufficient control and documentation procedures
in 2005 and prior years relating to certain processing, recording, summarizing
and reporting processes.


                                       24
<PAGE>

The Fund had the following material weaknesses. These weaknesses resulted in the
restatement of our initial Form 10, filed as Form 10/A, on November 13, 2006.

     o    Lack of sufficient communication and documentation, and lack of
          appropriate procedures surrounding pre and post-closing procedures
          including reconciliations and analytical reviews;
     o    Staff lacking sufficient technical expertise in the oil and gas
          industry, as well as GAAP and SEC requirements;
     o    Insufficient training programs, and policies and procedures on
          financial controls, to ensure the ongoing application and execution of
          controls; and
     o    Lack of resources necessary to perform consistent, routine analytical
          reviews of the financial results, including key balance sheet and
          income statement account analyses.

(d)     Material Weaknesses Remediation Plans

The Manager is committed to the remediation of these material weaknesses, as
well as to the continued improvement of the Fund's overall system of internal
control over financial reporting. Management has developed remediation plans for
each of the weaknesses, and has undergone efforts to strengthen the existing
finance organization and systems across the Fund. These efforts include the
addition of finance resources which provided technical support and oversight for
our financial processes. In addition, various employees have attended training
programs. The Fund has also utilized additional resources to assist in the
program management aspect of each material weakness in its remediation plan.


                                       25
<PAGE>

The Fund currently is executing its remediation plan that includes the
following:

     o    Adopting a more rigorous approach to communicate, document and
          reconcile the detailed components of pre and post-closing procedures
          including developing policy and procedure manuals and detailed
          checklists;
     o    Expanding staffing and resources, including the continued use of
          external third party assistance;
     o    Creating detailed training programs, and policies and procedures on
          financial controls, to ensure ongoing application and execution of
          controls; and
     o    Developing tools to perform consistent, routine analytical reviews of
          the financial results, including key balance sheet and income
          statement account analyses.

Part II. Other Information

Item 5.  Other Information

From the date of inception of the Fund through November 21, 2006, there were no
"reportable events" as defined in Item 304(a)(1)(v) of Regulation S-K.



                                       26
<PAGE>


Item 6.       Exhibits

       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.



                                       27
<PAGE>


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

Dated: November 21, 2006                RIDGEWOOD ENERGY O FUND, LLC

                            By:    /s/  ROBERT E. SWANSON
                                 Name:  Robert E. Swanson
                                Title:  President and Chief Executive Officer
                                        (Principal Executive Officer)

Dated: November 21, 2006
                            By:    /s/  KATHLEEN P. MCSHERRY
                                 Name:  Kathleen P. McSherry
                                Title:  Senior Vice President and Chief
                                        Financial Officer (Principal Financial
                                        and Accounting Officer)


                                       28
<PAGE>

              Exhibit Index

       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.

                                       29