SECURITIES AND EXCHANGE COMMISSION
                             Washington, D.C. 20549

                                   FORM 10-Q
                                  -----------

                                   (Mark One)

     [X] QUARTERLY REPORT PURSUANT TO SECTION 13 or 15(d) OF THE SECURITIES
                             EXCHANGE ACT OF 1934.

                For the quarterly period ended September 30, 2010
--------------------------------------------------------------------------------

                                      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 000-9519
                                               --------

                            REGENT TECHNOLOGIES, INC.
--------------------------------------------------------------------------------
             (Exact name of registrant as specified in its charter)



             COLORADO                                     84-0807913
--------------------------------------------------------------------------------
     (State or other jurisdiction of                   (I.R.S. Employer
     incorporation or organization)                   Identification No.)


                             5646 Milton, Suite 722
                              Dallas, Texas 75206
                    (Address of principal executive offices)

                                  214-694-2227
                          (Issuer's telephone number)

                         Regent Petroleum Corporation
                            (Former name of Issuer)


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 (the
"Exchange  Act") 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 a  non-accelerated  filer.  See definition of "accelerated
filer and large accelerated filer" in Rule 12b-2 of the Exchange Act.

Large accelerated filer                       Accelerated filer
                        ---                                             ---

Non-accelerated filer                         Smaller reporting company
                        ---                                             ---
(Do not check if a smaller reporting company)



Indicate by check mark whether the  Registrant is a shell company (as defined in
Rule 12b-2 of the Exchange Act).

                   Yes                                 No   X
                       ------                             ------

The number of outstanding shares of the issuer's only class of common stock as
of November 1, 2010 was 22,326,900.


<PAGE>


                    REGENT TECHNOLOGIES, INC. AND SUBSIDIARY
                          (A DEVELOPMENT STAGE COMPANY)

                               INDEX TO FORM 10-Q

                               September 30, 2010

                                                                       Page Nos.
                                                                       --------

                        PART I.  FINANCIAL INFORMATION

Item 1.  Financial Statements

  Consolidated Balance Sheets (Unaudited)                                  1
    at September 30, 2010 and December 31, 2009 (Audited)

  Consolidated Statements of Operations (Unaudited)                        2
    For the Three and Nine Months Ended September 30, 2010 and 2009
    For the Period from Inception (January 1, 1999) to
      September 30, 2010

  Consolidated Statements of Cash Flows (Unaudited)                        3
    For the Nine Months Ended September 30, 2010 and 2009
    For the Period from Inception (January 1, 1999) to
      September 30, 2010

  Notes to Consolidated Financial Statements                               4


Item 2.  Management's Discussion and Analysis of Financial Condition
            and Results of Operations                                     15

Item 3.  Quantitative and Qualitative Disclosures About Market Risk       27

Item 4.  Controls and Procedures                                          27

                          PART II. OTHER INFORMATION

Item 1.  Legal Proceedings                                                27

Item 1A. Risk Factors                                                     27

Item 2.  Changes in Securities                                            34

Item 3.  Defaults Upon Senior Securities                                  34

Item 4.  Submission of Matters to a Vote of Security Holders              34

Item 5.  Other Information                                                34

Item 6.  Exhibits and Reports on Form 8-K                                 35

SIGNATURE                                                                 36

EXHIBIT INDEX                                                             37


<PAGE>


                          PART I. FINANCIAL INFORMATION



Item 1.  Financial Statements
-------  --------------------

                    REGENT TECHNOLOGIES, INC. AND SUBSIDIARY
                          (A DEVELOPMENT STAGE COMPANY)
                           CONSOLIDATED BALANCE SHEETS

<TABLE>
<S>                                                                   <C>                   <C>
                                                                        September 30,          December 31,
                                                                            2010                  2009
                                                                    ------------------    ------------------
                                                                        (Unaudited)            (Audited)
                                 ASSETS
CURRENT ASSETS
   Cash in bank                                                         $    1,243            $    5,297
                                                                          ---------             ---------
Total Current Assets                                                         1,243                 5,297

Long-term note receivable, stockholder                                           -                70,000

Property and equipment, at cost, based on the full cost
   method of accounting for oil and gas properties                          91,278                10,993

   Less - accumulated depreciation, depletion and amortization            ( 11,172)             ( 10,993)
                                                                         ---------             ---------
Total property and equipment, net (Note 4)                                  80,106                     -

Investment in affiliate (Note 6)                                           386,316               395,620
                                                                         ---------             ---------
TOTAL ASSETS                                                            $  467,665            $  470,917
                                                                         =========             =========


                 LIABILITIES AND STOCKHOLDERS' EQUITY

CURRENT LIABILITIES
   Accounts payable, trade                                              $      634            $    2,606
   Note payable, related parties                                             2,750                 8,850
   Accrued interest payable                                                    656                   265
                                                                         ---------             ---------
Total current liabilities                                                    4,040                11,721
                                                                         ---------             ---------

STOCKHOLDERS' EQUITY
   Convertible Preferred stock, $.10 par value, 1,000,000
     shares authorized, 99,500 and 94,500 shares issued
     and outstanding, Regent Natural Resources Co.                           9,950                 9,450
   Preferred stock, $.10 par value, 30,000,000
     shares authorized, no shares issued and
     outstanding, Registrant                                                     -                     -
   Common stock, $.01 par value, 100,000,000
     shares authorized, 22,326,900 and 8,487,456
     shares issued and outstanding                                         223,269                84,875
   Paid-in capital in excess of par                                      3,713,795             3,815,795
   Accumulated deficit (including net loss of $135,390
     accumulated since reentering the development stage)                (3,483,389)           (3,450,924)
                                                                         ---------            ---------
                                                                           463,625               459,196
                                                                         ---------             ---------
TOTAL LIABILITIES AND STOCKHOLDERS' EQUITY                              $  467,665            $  470,917
                                                                         =========             =========


The accompanying notes are an integral part of the consolidated financial statements.

</TABLE>

                                       1
<PAGE>

                    REGENT TECHNOLOGIES, INC. AND SUBSIDIARY
                          (A DEVELOPMENT STAGE COMPANY)
                      CONSOLIDATED STATEMENTS OF OPERATIONS
          FOR THE THREE AND NINE MONTHS ENDED SEPTEMBER 30, 2010 AND 2009
                        AND FOR THE PERIOD JANUARY 1, 1999
                              THROUGH SEPTEMBER 30, 2010
                                   (UNAUDITED)
<TABLE>

                                           For the          For the           For the          For the
                                            three            three              nine             nine           Cumulative
                                            months           months            months           months      Since Re-entering
                                       ended September  ended September   ended September  ended September  Development Stage
                                           30, 2010         30, 2009          30, 2010          30, 2009      January 1, 1999
                                         ------------     ------------      ------------      ------------      ------------
<S>                                    <C>              <C>               <C>               <C>               <C>

Revenues                                 $         -      $         -       $        -        $        -        $        -

Operating expenses:
    General and administrative                 6,022            5,054           20,405            18,650           337,084
    Depreciation expense                          89                -              179                 -               179
                                           ---------        ---------        ---------         ---------         ---------
Operating loss                              (  6,111)        (  5,054)        ( 20,584)         ( 18,650)         (337,263)
                                           ---------        ---------        ---------         ---------         ---------
Other income and (expense):
    Gain on fair value measurement                 -                -                -                 -           103,201
    Transfer on fair value measurement             -         (  8,230)        (  9,304)         (  8,230)         ( 44,966)
    Gain on extinguishment of debt                 -                -                -                 -           145,340
    Gain on sale of investment                     -                -                -                 -            76,581
    Stock grant expense                     (  1,200)               -         (  3,394)         (  2,250)         ( 41,366)
    Interest, net                           (     63)        (    559)             817          (  1,273)         ( 36,917)
                                           ---------        ---------        ---------         ---------         ---------
Total other income (expense)                (  1,263)        (  8,789)        ( 11,881)         ( 11,753)          201,873

Income (loss) from continuing operations
  before income taxes                       (  7,374)        ( 13,843)        ( 32,465)         ( 30,403)         (135,389)

Provisions for income taxes                       -                 -                -                 -                 -
                                           ---------        ---------        ---------         ---------         ---------
Net income (loss)                           (  7,374)        ( 13,843)        ( 32,465)         ( 30,403)        $(135,390)
                                           =========        =========        =========         =========         =========

Net income (loss) per common share
   (basic and diluted)                     $       -        $       -        $       -         $       -
                                           =========        =========        =========         =========

Weighted Average Shares Outstanding       10,951,955        7,262,456        9,321,817         7,158,894


The accompanying notes are an integral part of the consolidated financial statements.

</TABLE>

                                       2
<PAGE>


                    REGENT TECHNOLOGIES, INC. AND SUBSIDIARY
                          (A DEVELOPMENT STAGE COMPANY)
                      CONSOLIDATED STATEMENTS OF CASH FLOWS
             FOR THE NINE MONTHS ENDED SEPTEMBER 30, 2010 and 2009
                       AND FOR THE PERIOD JANUARY 1, 1999
                           THROUGH SEPTEMBER 30, 2010
                                (UNAUDITED)
<TABLE>
<CAPTION>
						  		   		                     Cumulative
                                                                                                  Since Re-entering
                                                          For the Nine Months Ended September 30, Development Stage
                                                                 2010               2009          January 1, 1999
                                                             ------------       ------------        ------------
<S>                                                           <C>                <C>                 <C>
CASH FLOWS FROM OPERATING ACTIVITIES:
  Net income (loss)                                           $( 32,465)          $( 30,403)          $(135,390)
  Adjustments to reconcile net income (loss) to net
   cash used in operating activities:
     Depreciation                                                   179                   -               3,941
     Gain (loss) from fair value measurement                          -               8,230            (103,201)
     Change in fair value measurement                             9,304                   -              44,966
     Gain from extinguishment of debt                                 -                   -            (145,340)
     Gain from sale of investment                                     -                   -            ( 76,581)
     Note issued for settlement expenses                              -                   -              20,000
     Common stock issued for services                             3,394               2,250              46,366
     Common stock issued in legal settlement                          -                   -              14,000
     Decrease in settlements and note receivable                      -                   -               4,800
     Decrease in other assets                                         -                   -               1,967
     Increase in allowance for uncollectible settlements              -                   -              79,892
     Increase (decrease) in accounts payable, trade            (  1,972)              4,801              31,965
     Increase (decrease) in accrued interest payable                391               1,274              25,393
                                                              ---------           ---------           ---------
        Net Cash Used In Operating Activities                  ( 21,169)           ( 13,848)           (187,222)
                                                              ---------           ---------           ---------
CASH FLOWS FROM INVESTING ACTIVITIES:

  Investment in affiliates                                            -                   -            (350,000)
  Capital expenditures for computer equipment                  (  1,785)                  -            (  1,785)
  Proceeds from sale of investments                                   -                   -             100,000
                                                              ---------           ---------           ---------
        Net Cash Used In Investing Activities                  (  1,785)                  -            (251,785)
                                                              ---------           ---------           ---------
CASH FLOWS FROM FINANCING ACTIVITIES:

  Proceeds from note payable - related party                          -                   -             110,055
  Proceeds from sale of Preferred Stock                          25,000              22,500             427,500
  Proceeds from note payable - stockholder                            -              12,755              20,000
  Repayments of notes payable                                  (  6,100)                  -            (117,305)
                                                              ---------           ---------           ---------
        Net Cash Provided By Financing Activities                18,900              35,255             440,250
                                                              ---------           ---------           ---------
Net Increase (Decrease) in Cash                                (  4,054)             21,407               1,243

Cash At Beginning Of Period                                       5,297                 886                   -
                                                              ---------           ---------           ---------
Cash At End of Period                                         $   1,243           $  22,293           $   1,243
                                                              =========           =========           =========



                      SUPPLEMENTAL SCHEDULE OF NON-CASH INVESTING AND FINANCING ACTIVITIES
                      --------------------------------------------------------------------

    Common stock issued for conversion of notes payable       $       -           $       -           $ 193,840

    Common stock issued for oil and gas property transfer     $   8,500           $       -           $   8,500

    Common stock issued for director stock awards             $   2,194           $   2,250           $  25,166

    Common stock issued for bonus compensation                $       -                   -           $  20,000

    Common stock issued for payment of services               $   1,200           $       -           $   1,200

    Common stock returned in failed consideration and
    debt settlement                                           $       -           $       -           $ 510,960

    Note receivable as partial consideration for
    purchase of preferred stock                               $       -           $       -           $  70,000

    Cancellation of note receivable as partial
    consideration for oil and gas property transfer           $( 70,000)          $       -           $( 70,000)

    Repayment of note payable transferred directly to
    MacuCLEAR upon sale to GHI, Ltd.                          $       -           $       -           $(150,000)

    Partial sale of MacuCLEAR holdings to GHI, Ltd.           $       -           $       -           $ 148,500

    Issuance of common stock upon MacuCLEAR sale to
    GHI, Ltd.                                                 $       -           $       -           $   1,500


The accompanying notes are an integral part of the consolidated financial statements.

</TABLE>

                                        3
<PAGE>

                     REGENT TECHNOLOGIES, INC. AND SUBSIDIARY
                          (A DEVELOPMENT STAGE COMPANY)
               NOTES TO INTERIM CONSOLIDATED FINANCIAL STATEMENTS


Note 1.  BASIS OF PRESENTATION, ORGANIZATION AND BUSINESS OVERVIEW

The accompanying  unaudited  consolidated  financial  statements included herein
have been prepared by REGENT TECHNOLOGIES, INC. (the "Registrant" or  "Company")
pursuant to the rules and regulations of the Securities and Exchange  Commission
("SEC") for interim  financial information, and  do not include  all information
and footnotes required by accounting principles generally accepted in the United
States of America for complete financial  statements.  The results of operations
for such interim  periods  are not  necessarily  indicative of what may occur in
future periods.

These unaudited consolidated  financial statements should be read in conjunction
with the information  included in the Company's Report on Form 8-K dated October
8, 2010, and the  financial statements and  notes included on the  Form 10-Q for
the periods ending  March 31 and  June 30, 2010 and the Form 10-K for the period
ending  December 31, 2009, as filed with the SEC. The financial statements here-
in as of September 30, 2010, and for the three month periods ended September 30,
2010 and 2009, are unaudited and  in the opinion of management, the  information
provided  reflects all  material adjustments, consisting of normal and recurring
adjustments, necessary for a fair presentation of financial position and  of the
results for  the interim period presented.

In preparing the  accompanying  unaudited consolidated financial statements, the
Company  has  reviewed, as  determined necessary  by  the  Company's management,
events that have occurred after September 30, 2010, up until the issuance of the
financial statements, which occurred on November 5, 2010.

Organization and Business Overview
----------------------------------

The Company has one  subsidiary that  previously operated under the  name Regent
GLSC Technologies, Inc. ("Regent GLSC"), and was approved for a  name  change on
September 30, 2010 to Regent Natural Resources Co. ("Regent NRCo").  Regent GLSC
was formed to develop operations related to the life  sciences commercialization
process by working with  inventors and research teams. Regent GLSC's initial en-
try into life sciences was as the  management for MacuCLEAR, Inc. ("MacuCLEAR"),
a company organized  for the development of a treatment of the eye disease known
as dry age-related macular degeneration.  Regent NRCo's 6.85% ownership of Macu-
CLEAR was financed  through  the  sale of preferred  stock in  Regent NRCo.  Two
directors of Regent, David Nelson and Philip Ralston, comprise  forty percent of
the voting board  of MacuCLEAR.  Mr. Ralston has resigned as President of Regent
NRCo to give full time to MacuCLEAR's Phase II clinical trials and the Company's
CEO, David A. Nelson, was elected the President of Regent NRCo ("RNRCo").

As of the filing of this Form 10-Q, the Company  has restructured its management
team and refocused its business strategy. The Company's management team includes
David A. Nelson as  Chief Executive Officer,  John L. Clutter,  General  Manager
of the Energy Technology Division, Anton L. Prodanovic,  General  Manager of the
Natural Resources Division, and David L. Ramsour as Secretary. We have rights to
proprietary technologies  which we believe  provide Regent  an advantage  in the
energy industry.  Our business strategy is to exploit these advantages and gene-
rate long-term value for  our shareholders and partners.  We operate through two
business segments -- the  Energy Technology Division  and the  Natural Resources
Division.  We  intend to fund  operations initially from  the sale  of corporate
securities, including debt  and equity (see Management's Discussion and Analysis
herein).

                                       4
<PAGE>
The Company will  continue  to be a  "small business issuer"  and a "development
stage  company" as  defined pursuant to  the Securities Transfer Act of 1934, as
amended, following the Transfer.

Recent Events
-------------

On August 14, 2010, the Company entered into a  rights agreement with Epi-Cloyd,
Ltd. and Epi-Energy, Ltd. ("E-C") for the exclusive rights to develop  E-C gear-
boxes for the valve actuator and wind energy applications. Following a period of
eight months for the development of a gearbox prototype, Regent has the right to
enter into a  licensee agreement for  exclusive  rights to a  valve actuator and
wind  energy generation  field of use (see Management's  Discussion and Analysis
herein).

On  September 24, 2010,  the  Company  received  a  confirmation  that executive
management  of MacuCLEAR, Inc. had  rejected  the previously  announced purchase
offer tendered during  the second quarter by  Healthcare of Today, Inc. ("HOTI")
for 100% of the MacuCLEAR preferred  and common stock.  The rejection terminates
the agreement  by our  subsidiary to  sell  its  shares  of  MacuCLEAR  Series A
Preferred Stock to HOTI.  MacuCLEAR is  moving forward with its  Phase II clini-
cal trial for the  treatment of dry age-related macular degeneration with alter-
native funding.  During the  fourth quarter, MacuCLEAR  has  initiated  sales of
newly issued  preferred stock for $12.00 per share (see Note 10).

On September 29, 2010,  Signature Investor Group, LC and David A. Nelson, CEO of
the Registrant (the "Transferors"), executed a  Property Transfer Agreement (the
"Transfer Agreement") with  RNRCo the  Company's subsidiary, (the "Transferee").
Pursuant to the  terms  and conditions of the  Transfer Agreement, the principal
provisions of the transfer (the "Transfer") are:

          -  The Transferor assigned a 100% working interest and 75% net revenue
             interest in 66.574 gross acres in Hill County, Texas, which contain
             engineered Proved Undeveloped Reserves of 70.54M barrels;

          -  The Transferor also conveyed undeveloped oil and gas interests in a
             153 acre lease in Coke County, Texas;

          -  The conveyance included certain oil and gas production equipment;

          -  The Transferor received 13.5 million shares of new Company stock;

  	  -  Each of the parties provided  customary representations and warran-
             ties in the Transfer Agreement.

The foregoing description of the Transfer does not purport to be complete and is
qualified  in its  entirety by  reference to  the complete text of  the Transfer
Agreement, which  is filed as  Exhibit 2.1  hereto  and  incorporated  herein by
reference.

The valuation of the  transaction was  based primarily on  50% of the discounted
net  cash flow (PV-10) amount of  $2,015,700 for the Proved Undeveloped Reserves
transferred to RNRCo (see Note 4).  Because the  properties were  acquired from,
and the consideration was paid  to related  parties of the Company, the Transfer
was  recorded at the basis of the related parties in the amount of $78,500.

                                       5
<PAGE>

Note 2.  SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES

The significant  accounting policies of  Regent are  described in  Note 1 to the
consolidated  financial statements of the 2009  Form 10-K and in this Note 2 and
the  critical accounting policies  and estimates as  described  in  Management's
Discussion and  Analysis included in Item 7 of the 2009 Form 10-K and in  Item 2
of this report.  These financial statements and notes should be read in conjunc-
tion  with our audited  consolidated  financial  statements  and  the  financial
notes thereto included in Regent's Report on Form 10-K for the fiscal year ended
December 31, 2009.

Dependence on Oil and Gas Prices
--------------------------------

Under our  business plans as an independent  oil and gas producer,  our revenue,
profitability and future rate of  growth are substantially dependent on prevail-
ing prices  for oil and gas.  Historically,  the energy  markets  have been very
volatile, and there can be no assurance that oil and gas prices will not be sub-
ject to wide  fluctuations in the  future.  A substantial or extended decline in
oil or gas prices could have material adverse effects on our financial position,
results of operations, cash flows and access to capital and on the quantities of
oil and gas reserves that we can economically produce.

Oil and Gas Properties
----------------------

The Company  follows the  full-cost  method of  accounting under which all costs
associated with property acquisition, exploration and development activities are
capitalized.  We capitalize  internal costs that can be directly identified with
our acquisition,  exploration and  development activities and do not include any
costs  related to production, general  corporate overhead or similar activities.
Capitalized costs are  amortized on a composite unit-of-production  method based
on proved oil  and gas reserves.  Estimates of our proved reserves as of October
1, 2010 were prepared by a third  party engineering  firm.

Proceeds from the sale of  properties are accounted for as reductions of capita-
lized costs unless such sales  involve a significant change in the  relationship
between  costs and  the value of  proved  reserves or  the  underlying  value of
unproved properties, in which  case a gain or loss is recognized.  The  costs of
unproved  properties are excluded  from  amortization  until the  properties are
evaluated.  We review all of our unevaluated  properties  quarterly to determine
whether or not  and to what extent  proved reserves  have been  assigned  to the
properties and otherwise if impairment has occurred.  Unevaluated properties are
grouped by major prospect area where  individual property costs are not signifi-
cant and are  assessed  individually when individual  costs are significant.  We
review the carrying value of our properties under the full-cost accounting rules
of the  Securities and Exchange Commission on a quarterly basis.  This quarterly
review is  referred to as a ceiling test.  Under the  ceiling  test, capitalized
costs, less  accumulated amortization and related deferred income taxes, may not
exceed an  amount equal to the  sum of the present value of estimated future net
revenues (adjusted for cash flow hedges) less  estimated  future expenditures to
be incurred in  developing and  producing the proved  reserves, less any related
income  tax effects.

                                       6
<PAGE>
In calculating future net revenues, current prices are calculated as the average
prices  during the  preceding  12-month period  prior to the end of the  current
period, determined  as the un-weighted  arithmetical  average of  prices  on the
first day of each month within the  12-month period and  costs used are those as
of the end of the appropriate quarterly period.  Such prices are utilized except
where different prices are fixed and  determinable from applicable contracts for
the remaining  term of  those  contracts, including the  effects of  derivatives
qualifying as cash flow  hedges.  Two primary factors impacting the ceiling test
are reserve levels and  oil and gas prices, and  their  associated impact on the
present value of  estimated future net revenues.  Revisions to  estimates of oil
and gas  reserves and/or  an increase or  decrease in prices can have a material
impact on the present value of estimated future net revenues.  Any excess of the
net book value,  less  deferred income  taxes, is  generally  written  off as an
expense. We account for all  exploration costs (including seismic) in accordance
with Regulation S-X. Specifically, Rule 4-10 requires all companies that use the
full-cost  method  to  capitalize exploration costs as part of their oil and gas
properties  (i.e., the full-cost pool).  Exploration costs may be  incurred both
before acquiring the related property and after acquiring the property. Further,
these costs include, among other things,  geological and geophysical studies and
salaries and other expenses of geologists, geophysical crews and others conduct-
ing  those  studies.  Such costs  are  capitalized  as incurred.  Seismic  costs
directly associated  with the  acquisition and evaluation of unproved properties
are excluded from the amortization computation until it is determined whether or
not proved  reserves can be assigned to the properties.  The Company reviews its
unproved properties and associated seismic costs quarterly in order to ascertain
whether impairment has occurred.  To  the extent that  seismic costs  cannot  be
directly  associated with  specific unevaluated properties, they are included in
the amortization base as incurred.

Reserve Estimates
-----------------

Estimates of oil and gas reserves, by necessity, are projections based on geolo-
gic and engineering data, and there are  uncertainties inherent in the interpre-
tation of such data as well as the projection of  future rates of production and
the timing of development expenditures. Reserve engineering is a subjective pro-
cess of estimating underground  accumulations of  oil and gas that are difficult
to measure. The accuracy of any reserve estimate is a function of the quality of
available data,  engineering and geological  interpretation and judgment.  Esti-
mates of economically  recoverable oil and natural  gas reserves  and future net
cash flows necessarily depend upon a number of variable factors and assumptions,
such as historical  production from the area compared with production from other
producing areas, the assumed effects of regulations by governmental agencies and
assumptions governing future oil and natural gas prices, future operating costs,
severance taxes, development costs and workover costs, all  of which may in fact
vary considerably from actual results.  For these reasons, estimates of the eco-
nominally recoverable quantities of oil and natural gas attributable to any par-
ticular group of properties,  classifications of such  reserves based on risk of
recovery, and  estimates of the  future net  cash flows expected  therefrom  may
vary substantially. Any significant variance in the assumptions could materially
affect the estimated quantity and value of the reserves,  which could affect the
carrying value of oil and gas properties and/or the rate of depletion of the oil
and gas properties. Actual production, revenues and expenditures with respect to
our reserves will likely vary from estimates and such variances may be material.

                                       7
<PAGE>
Impairment of oil and gas properties
------------------------------------

Long-lived assets, including our  proved oil and gas reserves, are  assessed for
potential  impairment in accordance with  ASC 360, Accounting for the Impairment
or Disposal of Long-Lived Assets.

We review the carrying value of our long-lived assets whenever events or changes
in circumstances indicate that such carrying values may not be recoverable.  If,
upon review,  the sum  of the undiscounted  pretax  cash flows is  less than the
carrying value of  the asset group, the  carrying value is written down to esti-
mated fair value.  Individual assets  are grouped for impairment purposes at the
lowest level for which there are identifiable cash  flows that are largely inde-
pendent of the  cash flows of other  groups of assets, generally  on a field-by-
field basis.  The fair value of impaired  assets is determined  based on  quoted
market prices in  active markets, if  available, or upon the  present  values of
expected  future cash  flows using  discount  rates  commensurate with the risks
involved in the asset group.  The long-lived  assets of the  Company, which  are
subject to  periodic  evaluation, consist  primarily  of oil and gas  properties
and undeveloped leaseholds.

New Accounting Requirements
---------------------------

In January 2010, the Financial Accounting Standards Board (FASB) issued Account-
ing Standards Update No. 2010-03, Oil and Gas Reserve Estimation and Disclosures
(ASU 2010-03),  which  aligns the  FASB's  oil and  gas reserve  estimation  and
disclosure requirements under the SEC's final rule, Modernization of the Oil and
Gas Reporting  Requirements (Final Rule), which was issued  on December 31, 2008
and became effective  for the year ended December 31, 2009.  We have adopted the
Final Rule and ASU 2010-03 effective September 30, 2010 as a  change in account-
ing principle that is inseparable  from a change in accounting estimate.  Such a
change is hereby accounted for  prospectively under the authoritative accounting
guidance. Comparative disclosures applying the new rules  for periods before the
adoption of ASU 2010-03 and the Final Rule are not required.

In February 2010, the Financial Accounting Standards Board (FASB) issued ASU No.
2010-09, "Subsequent Events," which amends ASC 855 to  eliminate the requirement
to disclose the date through which management has evaluated subsequent events in
the financial  statements.  ASU No. 2010-09 was effective  upon issuance and its
adoption had no impact on Regent's financial  position, results of operations or
cash flows.

Effective January 1, 2010, the  Company partially adopted the provisions of FASB
ASU No. 2010-06,  "Improving Disclosures  about Fair Value  Measurements," which
amends ASC 820-10-50 to  require new disclosures  concerning  (1) transfers into
and out of Levels 1 and 2 of the fair value measurement hierarchy, and (2) acti-
vity in Level 3 measurements. The requirements to disclose separately purchases,
sales, issuances, and settlements in  the  Level 3 reconciliation  are effective
for fiscal  years beginning  after  December 15, 2010  (and for  interim periods
within  such years).  The Company has  applied the disclosure requirements rela-
tive to  the  Level 3  reconciliation in  the  current  quarter.  For additional
information, please refer to Note 6.

                                       8
<PAGE>
Note 3.  GOING CONCERN UNCERTAINTIES

As of the date of this  quarterly  report,  there is substantial doubt regarding
our ability to  continue as a going  concern as we have not generated sufficient
cash flow to fund our business  operations and  material commitments. Our future
success and  viability, therefore, are  dependent  upon our  ability to generate
capital financing.  We are  optimistic  that we  will be  successful in  our new
business  operations  and  capital  raising  efforts; however,  there  can be no
assurance that we will be successful in generating revenue or raising additional
capital. The failure to generate sufficient revenues or raise additional capital
may have a material and adverse effect upon the Company and our shareholders.

These consolidated financial  statements do  not give  effect to any adjustments
which would be necessary should  the Company  be unable to continue  as a  going
concern  and  therefore  be required  to realize  its assets  and  discharge its
liabilities in other than the normal course of business and at amounts different
from those reflected in the accompanying consolidated financial statements.


Note 4.  OIL AND GAS ASSETS

Property and Equipment
----------------------

Properties and equipment, net are comprised of the following:

                                                         September 30, 2010
                                                         ------------------
Unproved Oil and Gas Properties (1)                               $   4,802
Proved Oil and Gas Properties (1)                                    73,698
Other Equipment                                                      12,778
                                                         ------------------
                                                                     91,278
Accumulated Depreciation, Depletion and Amortization               ( 11,172)
                                                         ------------------
                                                                  $  80,106
                                                         ==================

(1)  Because the oil and gas properties were acquired from and the consideration
was paid  to related parties of the Company, the properties were recorded at the
the basis of the  related parties in the  amount of $78,500.

Asset Acquisition
-----------------

The table below sets forth our undeveloped and developed gross and net leasehold
acreage  acquired in the  Transfer Agreement  (see Note 1).  Undeveloped acreage
includes  acres on which wells  have not  been completed to a  point  that would
permit the commercial production, regardless of whether or not such acreage con-
tains proved reserves.  Undeveloped  acreage held by  production under the terms
of a lease is included in the Developed Acreage category total shown below.

            Undeveloped Acreage     Developed Acreage        Total Acreage
           ---------------------- --------------------- ---------------------
              Gross        Net       Gross       Net       Gross       Net
           ----------  ---------- ---------- ---------- ---------- ----------

               169          17        50          50        219         67


                                       9
<PAGE>
Title to Properties
-------------------

All the  leases for the  undeveloped acreage  summarized in  the preceding table
will expire  at the end of their  respective primary terms  unless prior to that
date, the existing  leases are renewed or  production has been obtained from the
acreage  subject to  the lease,  in which event the lease will  remain in effect
until the cessation of production. As is customary in the industry, we generally
acquire  oil and gas acreage  without any warranty of title  except as to claims
made by,  through or under the  transferor.  Although we have title to developed
acreage examined prior to the acquisition in  those cases in which  the economic
significance of the  acreage justifies the cost, there can be  no assurance that
losses will not result from title  defect or defects in the assignment of lease-
hold rights.


Oil and Gas Reserves
--------------------

All of our reserves and near term prospects are located in the Texas Mexia-Talco
Fault Zone of the  East Texas Basin and the  Eastern Shelf of the Midland Basin,
both mature  producing oil and  gas horizons located in Texas.  On behalf of the
Transferor, the  independent  engineering firm  RCM Engineering, Inc. of Dallas,
Texas,  evaluated the  reserves acquired pursuant  to the Transfer and issued an
appraisal  report on oil and gas  reserve estimates as of December 31, 2009, and
updated as of October 1, 2010 which are included in the following table:


Gas and Oil Properties, net (1):
   Proved Developed Crude Oil and
   Condensate reserves-Bbls                                0
   Proved Undeveloped crude oil and
   Condensate reserves-Bbls (2)                       70,540
                                                 -----------
   Total proved crude oil and condensate
     Reserves-Bbls                                    70,540
                                                 ===========

Present value of estimated future net cash flows
  before income taxes, discounted at 10% (3)      $2,015,700


(1) Reflects the estimate of the  net proved oil reserves, future  net revenues,
and the present value  of future net revenues (PV-10).  The only Proved Reserves
the Company has are Proved Undeveloped Reserves.

(2) "Proved Undeveloped Reserves" are reserves that are expected to be recovered
from new wells on undrilled acreage, or from existing wells where an expenditure
is required for recompletion.

(3) Standardized measure is the present value of estimated future net revenue to
be generated  from the  production of proved reserves, determined  in accordance
with the rules and  regulations of the SEC  (using prices and costs in effect as
of the date of estimation), less  future development, production  and income tax
expenses, and  discounted at 10% per annum to  reflect the  timing of future net
revenues.  The  standardized measure  does  not reflect  any  future  income tax
expenses  because it was not  subject to income taxes.  The standardized measure
shown should not be  construed as the current market value of the reserves.  The
10% discount factor used to  calculate present value, which is  required by FASB
pronouncements, is not  necessarily the  most  appropriate  discount  rate.  The
present value, no matter  what discount rate is used, is materially  affected by
assumptions as to timing of future production, which may prove to be inaccurate.

The Company is not  aware of any major  discovery or other  favorable or adverse
event that is  believed to  have caused a  significant  change in the  estimated
proved reserves since December 31, 2009.

                                       10
<PAGE>
Note 5.  CAPITAL STRUCTURE DISCLOSURES

Common and preferred stock
--------------------------

The Company's capital  structure is  complex and consists of preferred stock and
a general class of common stock. The Company is  authorized to issue 130,000,000
shares  of stock, of  which 30,000,000 have  been designated as preferred shares
with  a par  value per share of $.10, and  100,000,000 have  been  designated as
common shares with a par value per share of $.01. As of the date of this filing,
there is no preferred  stock outstanding and there are 22,326,900 shares of com-
mon stock outstanding.  This compares to 7,262,456 shares for the same period in
2009  with the  difference due to the 13,500,000 shares of  common shares issued
under the Transfer Agreement  (see Note 1) and the  stock issuances under stock-
based compensation (see Note 7).

Holders of  Regent's common stock are entitled to one vote for each share on all
matters submitted to a  stockholder vote.  Holders of  common stock  do not have
cumulative  voting rights.  Therefore,  holders of a  majority of  the shares of
common stock  voting for the  election of directors can  elect all of the direc-
tors.  Holders of the  Regent's common stock representing a majority of the vot-
ing power of  Regent's capital  stock issued, outstanding  and entitled to vote,
represented in  person or by proxy, are  necessary to constitute a quorum at any
meeting of  stockholders.  A vote by the  holders of a majority of Regent's out-
standing  shares is required to effectuate certain fundamental corporate changes
such as  liquidation,  merger or an  amendment to Regent's  articles of incorpo-
ration.

Holders of Regent's  common  stock are entitled  to share in  all dividends that
the  board of  directors, in its  discretion,  declares  from legally  available
funds.  In the event of liquidation, dissolution  or winding up,  each outstand-
ing share entitles its holder to  participate pro rata in all assets that remain
after payment  of liabilities and after  providing for each  class of  stock, if
any, having  preference  over the  common stock.  Regent's common  stock  has no
pre-emptive  rights, no conversion rights and there are no redemption provisions
applicable to the Regent's common stock.

Stock options
-------------

No options, warrants or similar rights are outstanding  as of this report date.

Subsidiary preferred stock
--------------------------

On April 18, 2007, Regent NRCo  accepted  purchase  agreements in a total amount
of $150,000 received  from  four purchasers  of a  private offering of shares of
of Series A  Convertible Preferred Stock ("Regent NRCo Preferred Stock").  Under
the accepted  purchase agreements, the subscribers purchased through a Preferred
Stock  Purchase  Agreement  30,000 shares  of Regent NRCo's Series A Convertible
Preferred Stock at $5.00 per share. The stock was sold under a private placement
offering  to  sell 25% of the  equity of  Regent NRCo for $1,250,000 in  $50,000
units.  Each unit is  convertible  into 10,000  shares of common stock of Regent
NRCo plus 4,800 shares of common stock of MacuCLEAR. Including the initial sales
on April 18, 2007, Regent NRCo  has accepted Preferred Stock purchase agreements
from additional investors in the total amount of $497,500.  If all of the uncon-
verted shares of the Series A  Preferred  Stock were to  be converted to  common
stock of  Regent NRCo, the Company's  ownership of Regent NRCo  would be diluted
to approximately 90%.

                                       11
<PAGE>
Note 6.  FAIR VALUE MEASUREMENTS

The Company has adopted ASC 820  which defines fair value and the framework  for
using fair value to measure  assets  and  liabilities,  and  expands disclosures
about fair value measurements.  The  statement applies whenever other statements
require or permit assets or liabilities  to be  measured at fair value.  ASC 820
established the following fair value hierarchy that  prioritizes the inputs used
to measure fair value:

  o    Level 1 -- Unadjusted  quoted prices in active markets for identical,
       unrestricted  assets  or  liabilities  that  are  accessible  at  the
       measurement date;

  o    Level 2 -- Quoted  prices  which are  not active, or inputs  that are
       observable (either directly or indirectly) for substantially the full
       term of the asset or liability; and

  o    Level 3 -- Significant unobservable inputs that reflect the Company's
       own assumptions about the assumptions  that market participants would
       use in pricing an asset or liability.

The following  table presents  our financial  assets and  liabilities  that were
accounted  for at fair value on a recurring basis by level within the fair value
hierarchy:

<TABLE>
<CAPTION>

                                                            Fair Value Measurements Using
                                                         --------------------------------------
                 September 30, 2010                       Level 1       Level 2      Level 3
                 ------------------                     -----------   ----------   -----------
<S>                                                      <C>           <C>           <C>
Investment in affiliate............................      $       -     $       -     $ 386,316

                 December 31, 2009
                 -----------------

Investment in affiliate............................      $       -     $       -     $ 395,620
</TABLE>

The Company is responsible for the valuation process and as part of this process
may use  data  from  outside  sources in  establishing fair value.  The  Company
performs  due  diligence  to  understand  the inputs  used or  how  the data was
calculated or derived.  The Company corroborates the  reasonableness of external
inputs in the valuation process.  Cash, accounts payable, and other current lia-
bilities are carried  at book value amounts  which approximate fair value to the
short-term maturity of these instruments.

Non-financial assets and liabilities
------------------------------------

The  Company  discloses or recognizes its  non-financial assets and liabilities,
such as  impairments of  long-lived assets and  oil and gas  properties, at fair
value on a  nonrecurring basis.   As  none of the  Company's other non-financial
assets and  liabilities were impaired as of September 30, 2010 and no other fair
value measurements  were  required  to be recognized on  a non-recurring  basis,
additional disclosures were not provided.

                                       12
<PAGE>
Financial assets and liabilities - Investment in affiliate
----------------------------------------------------------

Our financial  assets and liabilities  are measured at fair value on a recurring
basis.  As of this  quarterly filing, the  Company's  subsidiary  holds  126,428
shares of MacuCLEAR Preferred Stock, of  which  95,858 shares  are  beneficially
held for the holders of subsidiary  Preferred Stock. The Company has adopted ASC
820 which defines fair  value and the framework for using  fair value to measure
assets  and  liabilities, and expands disclosures about fair value measurements.
Under this process, the Company has determined the fair value for the  MacuCLEAR
Preferred  stock, as of the end of this quarter, has not changed from the  $4.50
per  share for the  prior period based on  pending agreements  to sale MacuCLEAR
Preferred Stock for up to $12.00 per share (see Note 10).

Due to the sale in  January 2010 of 5,000 shares of Regent NRCo Preferred Stock,
the number of shares beneficially owned  by the Company was reduced  from 35,454
to 30,570.  As a  result of our  reduced  ownership, the  amount of $9,304 was a
transfer out of the  Level 3 valuation for  the first quarter and was treated as
a net loss for this annual period.

The following  table sets forth a  reconciliation of  changes for the  three and
nine month periods ended September 30, 2010 in  the fair value  of the financial
assets classified as Level 3 in the fair value hierarchy:


                                                 Three Months     Nine Months
                                               Ended 9/30/2010  Ended 9/30/2010
                                               ---------------  ---------------

Balance at beginning of period                 $      386,316   $       395,620
Realized gain/(loss)                                        -                 -
Change in unrealized
appreciation/(depreciation)                                 -                 -
Net purchase/sales                                          -                 -
Net transfers in and/or out of Level 3                      -          (  9,304)
                                               --------------   ---------------
Balance at end of period                       $      386,316   $       386,316
                                               ==============   ===============

Note 7.  STOCK-BASED COMPENSATION

In December 2007, Regent entered  into restricted  common stock award agreements
with  its directors  under which it  may be required  to  issue  up to 2,000,000
shares of  common stock, 500,000 shares  to four directors. The restricted stock
awards vest over 36 months  from the date of  first service as a  Director which
resulted in the grant of 500,000 shares to the President in 2007 and 347,223 and
450,000  shares to the  remaining Directors in  2007 and 2008, respectively. The
grant was valued at $2,000  for tax purposes, being  the value of  the shares on
the day the  agreement  was  completed.  The Company has  valued  the  shares at
$20,000 for book  purposes, being  the stock par  value.  The  total cost of the
restricted  stock grant  will be recognized  in  the  consolidated  statement of
operations at the dates of vesting over an estimated  period of three years.  We
recognized the amounts of $4,500 and $5,000 as stock-based director compensation
expense for the fiscal  periods ended 2009 and 2008, respectively, based  on the
par value of  the stock issued.

Stock-based  compensation expense during the  first nine months of 2010 and 2009
$3,394 and $2,250,  respectively, and is included in Other Expense in the Conso-
lidated  Statement of Operations. As of September 30, 2010, 33,333 shares remain
unissued and unvested under the director award agreements.

                                       13
<PAGE>
Note 8. RELATED PARTY TRANSACTIONS

Property Transfer Agreement
---------------------------

On September 29, 2010, Signature Investor Group, LC ("SIG") and David A. Nelson,
CEO of the Registrant and  co-owner of SIG with his spouse, executed a  Property
Transfer  Agreement  with  RNRCo (see Note 1).  After  the  consummation  of the
Transfer Agreement, the  related  parties  control  approximately  80.5%  of the
outstanding common stock of the Registrant.

Note receivable, stockholder
----------------------------

Effective December 30, 2009, the  Board of the Company and  the  Board of Regent
NRCo Technologies, Inc.  approved  the  sale  of  15,000  shares  of  subsidiary
Series A Preferred Stock to the Chairman and CEO of  Regent and  Regent NRCo for
$5.00 per share. The acquisition required a payment of $5,000 plus the execution
of a  promissory  note  in the  amount of $70,000, which  was forgiven under the
the Property Transfer Agreement.

Notes payable
-------------

Beginning in  2005, the  Company borrowed  various amounts for general corporate
purposes  under a note  payable to NR Partners, a  partnership  comprised of the
President as  a partner and  director David Ramsour as a  partner.  The total NR
Partners amount due and payable at September 30, 2010 was $2,750. The promissory
note is a demand note and pays interest at 8.5 percent per annum.

Preferred stock sale
--------------------

Effective  January 7, 2010, Regent's subsidiary  executed a Preferred Stock pur-
chase agreement for the  purchase and sale of 5,000 shares of Series A Preferred
Stock for $5.00 per share with the spouse of the CEO of the Company.

Note 9.  COMMITMENTS

The  capital commitments to undertake the  drilling activities necessary to ful-
fill the exploration and development of the Proved Undeveloped Reserves required
under the  acquired leaseholds pursuant to the  Transfer Agreement were assessed
and estimated by the  management to be in the region of $350,000.  Unless we are
able to raise  sufficient  capital, we  will not  be able to  meet our leasehold
obligations and may not be able to continue as a going concern.


Note 10.  SUBSEQUENT EVENTS

On October 20, 2010,  MacuCLEAR, Inc.  accepted  agreements and  payment to sale
MacuCLEAR Preferred Stock for $12.00 per share.  This purchase and sale activity
will result in a positive change in the reported fair value of the  Registrant's
holding of MacuCLEAR Preferred Stock and the recording of a gain of $229,275 for
the fourth quarter.

                                       14
<PAGE>
Item 2.  Management's Discussion and Analysis of Financial Condition
-------  -----------------------------------------------------------
         and Results of Operations
         -------------------------

INTRODUCTION - STATEMENT OF FORWARD-LOOKING INFORMATION
-------------------------------------------------------

The Private Securities Litigation Reform Act of 1995 (the "Act") provides a safe
harbor for forward-looking  statements made by or on behalf of the Company.  The
Company  and its  representatives  may from  time to time make  written  or oral
statements that are  "forward-looking",  including  statements contained in this
report and other filings with the Securities and Exchange Commission, reports to
the  Company's  shareholders  and news  releases.  All  statements  that express
expectations, estimates, forecasts or projections are forward-looking statements
within the meaning of the Act. In addition,  other  written or oral  statements,
which constitute forward-looking  statements, may be made by or on behalf of the
Company. Words such as "expects", "anticipates", "intends", "plans", "believes",
"seeks", "estimates",  "projects",  "forecasts",  "may", "should", variations of
such words and similar expressions are intended to identify such forward-looking
statements.  Management cautions that forward-looking statements  are subject to
risks and uncertainties that could cause our actual results to differ materially
from  projections in  such  forward-looking statements. The risks, uncertainties
and other important factors that may cause our results to differ materially from
those projected  in such forward-looking statements are detailed under the "Risk
Factors" and  elsewhere  in our  Annual  Report on Form 10-K for our fiscal year
ended December 31, 2009.  We undertake no obligation to update a forward-looking
statement to reflect subsequent events, changed circumstances, or the occurrence
of unanticipated events.

In this Form 10-Q,  references to "we," "our," "us," the "Company,"  or "Regent"
refer to  Regent Technologies, Inc., a Colorado corporation, and Regent's wholly
owned subsidiary, Regent Natural Resources Co., a Texas corporation, is referred
to herein as "Regent NRCo."

The following  Management's Discussion and  Analysis of Financial  Condition and
Results of Operations ("MD&A") is intended  to assist the  readers to understand
Regent, our operations, and our  present business environment.  This MD&A should
be read in conjunction  with "Item 1.  Financial Statements" of  this  report on
Form 10-Q and the financial statements and notes in our Form 10-K filed  for the
period ending December 31, 2009  for a full understanding of our financial posi-
tion and results of operations for this nine month period.

This overview summarizes the MD&A, which includes the following sections:

|_|  Overview and Business Description
|_|  Critical Accounting Policies and Estimates
|_|  Results of Operations
|_|  Liquidity and Capital Resources
|_|  Risk Factors

                                       15
<PAGE>
---------------------------------
Overview and Business Description
---------------------------------

Regent Technologies, Inc., a  Colorado corporation, is listed on the pink sheets
under the trading  symbol "REGT".  The Registrant is a development stage company
engaged in the development of natural resources and related energy technologies.
The Company has one  subsidiary that  previously operated under the  name Regent
GLSC Technologies, Inc., and  was approved  for a  name  change on September 30,
2010  to  Regent Natural Resources Co. ("Regent NRCo").  Regent and  Regent NRCo
have rights to proprietary technologies which we believe provide us an advantage
in the industry.  Our business strategy is to exploit these advantages and gene-
rate  long-term value for our shareholders and partners.  We operate through two
business segments:
                           -Energy Technology Division
                           -Natural Resources Division

Our Mission is to accomplish our business strategy while maintaining the highest
standards of integrity and professionalism wherever we operate and promoting re-
sponsible energy now and in the future. Our Vision is to employ new technologies
to maximize the  production of petroleum  resources in an efficient and environ-
mentally safe manner while developing  new technologies for the increased use of
renewable energy.

                            ENERGY TECHNOLOGY DIVISION

Our Energy Technology Division is involved in identifying  and developing emerg-
ing  technologies which  impact energy production.  We are currently  focused on
the development of a distinctive gearbox  designed for petroleum valve actuators
and large  wind energy generators.   Known as the Epicloyd ("E-C") transmission,
the E-C Gearbox that we are developing for wind energy usage will be constructed
to provide a minimum of a decade of continuous service.  Though these are appro-
priate for installation of new large wind generators, the primary  market of the
gearboxes will be replacement of short-lived and  repeatedly-failed conventional
gearboxes currently in 1 to 3 megawatt wind generators located around the US.

We are also working to  apply the  unique performance of the  E-C Gearbox to the
control of  valve actuators.  Because of its durability  and ability to function
for many years in  locales beyond the reach of normal  maintenance services, the
E-C gearbox is able to  bring reliable performance and financial  benefit to its
users in the petroleum industry and beyond.

The objective of Regent's Energy Technology Division is to apply the E-C Gearbox
to a wide variety of global energy industries to both diversify and increase re-
venues for the  Company.  Specific  attributes that  place the E-C Gearbox above
competitors are:

-  Greatly reduced number of bearings and bearing failures
-  Elimination of tooth failure and destructive metal shavings
-  Great reduction in lubrication requirements
-  Low generation of heat
-  Extended durability, lower and simpler maintenance requirements
-  Scalable to virtually all size applications

                                       16
<PAGE>
Technology
----------

On August 14, 2010, the Company entered into a  rights agreement with Epi-Cloyd,
Ltd. and Epi-Energy, Ltd. (E-C) for the exclusive rights to develop an E-C Gear-
box for the valve actuator and  wind energy applications.  Following a period of
eight months for the development of a gearbox prototype, Regent has the right to
enter into a  licensee agreement for exclusive rights for the valve actuator and
wind energy generation fields of use.  Upon entering into the license agreement,
Regent will pay a minimum  royalty  payment of $12,500 per quarter for the first
twelve months and  $25,000 per quarter thereafter.

Epi-Cloyd, Ltd.  and Epi-Energy, Ltd. are  related private  technology companies
operating in  Dallas, Texas  and  focused on the  utilization of  their numerous
patents  covering a revolutionary  cyclic reduction  invention.  Their invention
increases  torque as a  plurality of  driver discs  rotate about a central shaft
member and engage an output  member via a low-friction, roller means.  The first
of seven related patents was issued in  March 2007 and all are within the  scope
of the Company's rights agreement.

Epi-Cloyd Application To Wind Energy
------------------------------------

Although the Company will be able to provide Epi-Cloyd transmissions for a great
variety of applications, it has  focused its energies for the foreseeable future
on meeting  the most serious  problems confronting  wind energy providers today.
These problems currently  revolve around the repeated and destructive failure of
conventional transmissions and the high cost of removing and replacing such gear
boxes in the field.

The combination of a  lower price of an  Epi-Cloyd transmission, the  savings of
timely orders, the lower maintenance requirements, and the savings from doubling
the life of a tower transmission produces a  significant saving to the customer.
The Company  expects to be  able to sell its  transmissions in a range of 75% of
the "aftermarket" price currently charged for conventional transmissions.  That,
combined with an expected doubling of unit life,  results in a unit cost that is
less than 50 percent of  current conventional  unit costs over a 10-year period.
In addition, the reduction in  unit maintenance and  costly in-field replacement
charges as well as lengthy down time, moves the E-C Gearbox replacement and ope-
rating cost lower to the  range of 30 percent of  current gearbox unit/operating
costs.  Under these conditions, the Company could consider higher unit prices to
cover contingencies and extended warranties and still create a healthy profit.

Epi-Cloyd Wind Energy Market
----------------------------

We are estimating that there will be 4,000 gearboxes going out of warranty every
year for the next few years in the United States only. This includes the current
installed base of GE's  most widely used turbine, the 1.5 MW,  which is reported
at 13.5K units. While we believe the Epi-Cloyd should be supplied as the initial
OEM transmission, overly  conservative  wind farm  financing entities  will push
back against  this new device for  at least the first five years of use.  So the
initial customer  base will be the wind farm operators who have 4,000 OEM trans-
missions with expiring warranties and  thus have the most to gain from using our
less expensive and  longer lasting product.  Primary efforts will focus on part-
nering with  generator providers  operating under  power purchase agreements for
equipment integrity.

                                       17
<PAGE>
Revenue Outlook
---------------

On the very conservative  presumption that in the first five  years of operation
the Company can grow market share from 2 to 15  percent while developing a brand
name in the market, we expect to generate over  $100 million in  profits in that
time frame on a conservative  gross  margin of 25% in the  US 1.5 MW turbine re-
placement  transmission market.  Prospects for new installation sales  and other
size turbine  replacement are expected  to generate  additional revenue and pro-
fits based on an estimated superior profit margin.

Near-Term Milestones
--------------------

We are seeking $1.5 million in external  funding to effectively position our E-C
effort for maximum return on investment in the shortest period of time.  An ini-
tial $300K is being sought from private investors and the balance will be raised
through non-dilutive licensing.  $300K is being  sought from  angel investors to
initiate  critical  prototype work  that confirms proof of  principle previously
demonstrated in an independent testing laboratory.  We will seek to  develop the
prototype under an agreement with a strategic partner currently in the wind tur-
bine business.

                          NATURAL RESOURCES DIVISION

Our Natural Resources Division  has  initiatives  for  identifying  oil  and gas
fields with  proven reserves that  can be significantly  increased and developed
with conservative  strategies of proximity and our proprietary enhancement tech-
nologies.  Our core technology involves restoring or increasing the productivity
of oil wells which have insufficient reservoir drive due to formation damage.

In addition, for confirming the  presence of abandoned reserves as well as iden-
tifying  exploratory prospects, we use a  proprietary passive  survey technology
which provides a  high degree of accuracy in the determination of commercial oil
and  gas fields.  When combined with  other measures of  potential reserves, our
risk reduction processes have provided a high level of precision for mapping the
aerial extent of geological closures and hydrocarbon trapping geometries.

The objective of our Natural Resources Division is to  selectively acquire pros-
pects where reserves can be identified with confidence, can be economically pro-
duced and where levels of production can be raised quickly and sustained for the
highest return on investment.

Prospective Exploration and Production Activities
-------------------------------------------------

We intend to grow reserves and production economically, primarily by:  (1) major
workover of an existing wellbore on a leasehold with Proved Undeveloped Reserves
including the possibility of deepening said wellbore to test the Woodbine Forma-
tion; (2) acquiring properties with reasonable risk-reward potential and by par-
ticipating in and or actively conducting drilling operations in order to further
exploit the  existing properties;  and (3) selectively pursuing strategic acqui-
sitions that can be improved with our production enhancement technologies.

                                       18
<PAGE>
Exploration activities  will normally be conducted  with the  Company  acquiring
undeveloped oil and gas leases  under prospects, and  carrying  out  exploratory
drilling  on  the  prospective leasehold  with the Company  retaining a majority
interest in the prospect.  Interests in the  property will sometimes  be sold to
key employees and associated  companies at cost.  Also, interests may be sold to
third parties with the Company retaining an overriding royalty interest, carried
working interest, or a reversionary interest.

Regent  intends to rely on joint ventures  with qualified  operating oil and gas
companies to operate its projects through the exploratory and production phases.
This  will  reduce  general  and  administrative   costs  necessary  to  conduct
operations.  As of the date of this filing,  Regent  is not operating any of the
oil and gas wells or prospects  in which it owns an interest.

All of our reserves and near term prospects are located in the Texas Mexia-Talco
Fault Zone of the  East Texas Basin and the  Eastern Shelf of the Midland Basin,
both mature  producing oil and  gas horizons located in Texas.

Mexia-Talco geologic overview
-----------------------------

The East Texas Basin is a structural embayment of the Gulf Coast Basin. While it
is bounded on the east by the Sabine Uplift and the  East Texas Oil Field, it is
bounded on the north and west by the Mexia-Talco Fault Zone and what are  called
the  Woodbine Fault-Line fields.  In its deepest part, the  basin is filled with
more than  13,000 feet (>3960 m) of Mesozoic and  Tertiary strata (Wood and Gue-
vara, 1981) that were structurally modified by mobilization of the Middle Juras-
sic Louann Salt (Lahee, 1929).  This salt  movement included the  development of
the Van salt dome which is overlain by the massive Woodbine Van Oil Field in Van
Zandt County in north central Texas.  The Woodbine Fault-Line fields run through
Milam, Falls, Limestone,  Freestone, Navarro, Henderson, and Kaufman counties in
east central Texas with related production in  Hill and Ellis counties.  The six
oil and gas  fields on  the west faults are Mexia  (Limestone County, discovered
1920), Currie (Navarro County, 1921), North Currie (Navarro County 1922), Powell
(Navarro County, 1923),  Richland (Navarro County, 1924), and Wortham (Freestone
County, 1924). Powell, Mexia, and Wortham are the most productive of the fields.

The first field to be discovered was Mexia in northwestern Limestone County, and
it introduced the concept  of fault-line production in the  Woodbine sands which
has continued through today. By January 1, 1993, the reporting fault-line fields
yielded annual production of 292,250 barrels of oil and 13,553,000 cubic feet of
casinghead gas.  Combined cumulative production for all of the fields climbed to
280,948,170  barrels of oil by 1993, after  more than seventy years of operation
(Railroad Commission of Texas, Annual Report of the Oil and Gas Division, Austin
1992).  Since 1993, all of the fault-line  fields have continued to produce with
new  drilling and  production, some of which  included original pressures in the
Woodbine formation and  enhanced production from zones above the Woodbine forma-
tion, primarily the  Austin Chalk.  The Company has three tracts in Hill County,
two of which have all of our Proved Undeveloped Reserves which are proven in the
Austin Chalk and Woodbine formations at less than 1,500 feet.  We are working on
an area of mutual interest in a multi-county area for future exploration.

                                       19
<PAGE>
Eastern Shelf geologic overview
-------------------------------

The depositional and tectonic history of the  Eastern Shelf of the Midland Basin
reveals  reservoir rocks  consisting of porous limestone,  dolomite, dolomitized
mudstone and wackestone, and lesser amounts of fine-grained  clastics frequently
associated  with evaporites, redbeds and  sabkha facies.  These rocks  appear to
have been  deposited in  platform edge,  open-shelf, intertidal, supratidal, and
restricted-shelf environments associated with platform growth. The Pennsylvanian
rests directly upon the eroded Ordovician Ellenburger over much of the area, al-
though in places a thin remnant of Mississippian lies between the  Pennsylvanian
and Ordovician.  The lower Pennsylvanian  was deposited upon a gently undulating
eroded surface, with the exception of some narrow grabens  that formed along the
east side of the  Eastern Shelf as part of the  north trending flexure that lies
between the deeper Midland Basin to the west, and the Bend Arch to the east. The
recurring gentle uplift  of many of the eroded pre-Pennsylvanian structures took
place during the  Pennsylvanian and influenced the  deposition of cleaner carbo-
nates or the growth of reefs in  association with the slightly shallower waters.
This is the reason for the  occurrence of minor oil accumulations in the Ordovi-
cian Ellenburger  dolomites beneath or near many of the  producing Pennsylvanian
reef fields.

Reservoir rocks consist of porous  limestone, dolomite, dolomitized mudstone and
wackestone, and  lesser  amounts of fine-grained  clastics frequently associated
with evaporites,  redbeds and  sabkha  facies.  These rocks  appear to have been
deposited in platform edge,  open-shelf, intertidal, supratidal, and restricted-
shelf environments associated with platform growth.  Reservoirs are contained in
Permian  Wolfcampian, Leonardian  Clear  Fork  Formations, and   Guadalupian San
Andres,  Grayburg,  Queen,  Seven Rivers and  Yates Formations.  Gross reservoir
thicknesses range up to 1,000 feet, porosities average 10 percent, and permeabi-
lities  average 6 mD. The drilling depths vary  from 3,000  to 10,000 feet.  The
Company has a small carried working interest in the first well drilled  on a 153
acre tract in Coke County.

Technology
----------

We will participate in  projects  utilizing  economically  feasible and advanced
technology  in  the  exploration  and  development  activities to  reduce risks,
lower costs, and more efficiently  produce oil and gas. Regent believes that the
availability  of cost effective 3-D seismic surveys makes its use in exploration
and development  activities  attractive  from a risk  management  perspective in
certain areas. In certain instances,  3-D seismic surveys more accurately inform
management in  evaluating  drilling  prospects than do conventional  2-D seismic
and  traditional  evaluation methods.  We  will also  use a  third-party passive
seismic survey which has proven effective through low frequency  passive seismic
data  analysis to find the so-called  direct hydrocarbon indicator.  This third-
party consulting group's passive survey  approach has resulted in an exploratory
success rate of 6 out of 10 tries instead of the industry 1 in 9.

Regent may supplement its exploration efforts with acquisitions of producing oil
and gas  properties.  We will seek to acquire  producing  properties that either
are  underperforming relative to  their potential or  possess Proven Undeveloped
Reserves for drilling and development.

                                       20
<PAGE>
Oil and Gas Outlook for 2010 and 2011
-------------------------------------

The following summarizes our goals and objectives for 2010 and 2011:

-  Participate in the rework or deepening of the existing wellbore on the
   acreage in Hill County to test the Woodbine formation;

-  Continue the development of the interest on the acreage in Coke County;

-  Pursue additional oil and gas asset and project acquisitions in common areas;

-  Maintain liquidity through increases in cash flow provided by operations
   and through a new credit facility borrowing base; and

-  Continue to build our operating staff and related capabilities.

------------------------------------------
Critical Accounting Policies and Estimates
------------------------------------------

Management's  discussion  and  analysis of  financial  condition  and results of
operations  is  based  on  the  accounting  policies used  and disclosed in this
quarterly  report  and  in  the  2009  consolidated   financial  statements  and
accompanying notes that  were prepared in  accordance with accounting principles
generally accepted in the  United States of America  and included as part of the
Company's annual  report  on  Form  10-K for the  year ended  December 31, 2009.
The  preparation  of the referenced consolidated  financial  statements required
management to make  estimates and assumptions that affected the reported amounts
of assets and liabilities and disclosure of contingent assets and liabilities at
the dates of the consolidated financial  statements and the reported  amounts of
expenses  during the  reporting periods.  Actual amounts or results could differ
from those estimates.

Our significant accounting policies and new requirements are discussed in Note 2
Summary of Significant Accounting Policies, of the Notes to Unaudited Consolida-
ted Financial Statements included in  Item 1. Financial Statements.  Please also
refer to our report on  Form 10-K for the period  ended  December 31, 2009 for a
more detailed discussion of our critical accounting estimates.

---------------------
Results of Operations
---------------------

Revenues
--------

The  Company had no sales for the quarterly periods ended September 30, 2010 and
September 30, 2009.

                                       21
<PAGE>
Operating Expenses
------------------

Operating  expenses  primarily include  accounting  and administrative expenses.
General  and  administrative  expenses  were $20,584 for the  nine  months ended
September 30, 2010 compared to $18,650 for the nine months  ended  September 30,
2009. The increase in administrative expenses is the result of more expenditures
for stock transfer fees, audit fees, and depreciation. Interest expense was $391
for the nine months  ended September 30, 2010 compared to $1,274 during the nine
months ended September 30, 2009,  due to the lower amount  outstanding under the
NR Partners promissory note.  Depreciation expense for the period was $179.

-------------------------------
Liquidity and Capital Resources
-------------------------------

As a development stage company, Regent has funded  operations through short-term
borrowings and equity investment sales in order to meet obligations.  Our future
0perations  are  dependent  upon  external funding and our ability  to  increase
revenues  and reduce expenses.  Management believes that sufficient funding will
be available  from additional related party borrowings and private placements to
meet our business  objectives  including  anticipated  cash   needs for  working
capital, for a reasonable period of time.

As  of  September 30, 2010, the Company had total assets  of  $467,665 and total
liabilities  of $4,040.  The  Company  has  borrowings under a note  payable  to
NR Partners, a  partnership  of  which  the  President and one  Director are the
partners. The NR Partners note bears interest at a rate of 8.5 percent per annum
(see Note 7).  The funds have been used  for general corporate purposes and  the
outstanding balance as of November 1, 2010 is $2,750.

As of the  date of this quarterly report, there is concern regarding our ability
to continue  as a  going  concern as  the Company has  not  generated sufficient
cash flow  to fund our  business operations and material commitments. Our future
success and  viability, therefore, are  dependent  upon  our ability to generate
capital financing.  We are  optimistic that we will be successful in our current
business  operations  and  capital  raising  efforts; however,  there  can be no
assurance that we will be successful in generating revenue or raising additional
capital. The failure to generate sufficient revenues or raise additional capital
may have a material and adverse effect upon the Company and our shareholders.

Off-Balance Sheet Arrangements
------------------------------

As of the date of this report, we do not have any off-balance sheet arrangements
that have or are  reasonably likely  to  have a  current or future effect on our
financial  condition, changes  in  financial  condition,  revenues or  expenses,
results of operations, liquidity, capital expenditures or capital resources that
are material to  investors.  The  term "off-balance sheet arrangement" generally
means any  transaction,  agreement or  other contractual arrangement to which an
entity  unconsolidated   with  us  is a  party, under  which  we  have:  (i) any
obligation arising under a guarantee contract, derivative instrument or variable
interest;  or (ii)  a  retained or  contingent interest in assets transferred to
such entity or  similar  arrangement  that serves as credit, liquidity or market
risk support for such assets.

                                       22
<PAGE>
------------
Risk Factors
------------

This report contains information that is forward-looking or relates to anticipa-
ted future events or results,  such as planned capital expenditures, the availa-
bility and sources of  capital resources to fund  capital expenditures and other
plans and objectives for  future operations.  Although  we  believe  that  these
expectations  are  reasonable,  this information is  based upon  assumptions and
anticipated  results that  are subject to  many uncertainties and risks.  Actual
results may vary  significantly  from those anticipated due to numerous factors,
including the other factors  affecting our business  described under the caption
"Risk Factors" in Item 1A of our  Annual Report on Form 10-K for  the year ended
December 31, 2009 and under Part II, Item 1A of this report.

Commonly Used Oil and Gas Terms
-------------------------------

Below are explanations of some commonly used terms in the oil and gas business.

 "Acquisition  of  properties"  are the costs  incurred to obtain  rights to
production  of oil and gas.  These costs  include the costs of acquiring oil and
gas leases and other interests.  These costs include lease costs, finder's fees,
brokerage fees, title costs, legal costs,  recording costs,  options to purchase
or lease interests and any other costs  associated  with the  acquisitions of an
interest in current or possible production.

     "Area of mutual  interest" means,  generally,  an agreed upon area of land,
varying in size, included and described in an oil and gas exploration  agreement
which  participants  agree will be  subject to rights of first  refusal as among
themselves,   such  that  any  participant  acquiring  any  minerals,   royalty,
overriding  royalty,  oil and gas leasehold  estates or similar interests in the
designated area, is obligated to offer the other participants the opportunity to
purchase their agreed upon  percentage  share of the interest so acquired on the
same basis and cost as  purchased  by the  acquiring  participant.  If the other
participants,  after a specific time period, elect not to acquire their pro-rata
share,  the acquiring  participant is typically then free to retain or sell such
interests.

     "Back-in  interests" involve the  transfer of interest in a property,  with
provision to the  transferor to receive a reversionary  interest in the property
after the occurrence of certain events.

     "Bbl" means barrel, 42 U.S. gallons liquid volume,  used in this  report in
reference to crude oil or other liquid hydrocarbons.

     "Bcf" means  billion cubic feet, used in this report in reference to gas or
gaseous hydrocarbons.

     "Bcfe"  means billions of cubic feet of gas  equivalent,  determined  using
the ratio of six thousand cubic feet of gas to one barrel of oil,  condensate or
gas liquids.

     "Carried interests" means, generally, a  working interest  which  does  not
bear its share of the exploration costs until a designated well has been drilled
and completed to the  casing point or to the tanks, depending  on the agreement,
after which point the carried interest  must bear its share of the costs of pro-
duction.

                                       23
<PAGE>
     "Casing  Point"  means  the point in time at which an  election  is made by
participants  in a well  whether to proceed with an attempt to complete the well
as a producer or to plug and abandon the well as a non-commercial  dry hole. The
election is generally made after a well has been drilled to its objective  depth
and an evaluation has been made from drill cutting  samples,  well logs,  cores,
drill  stem  tests and other  methods.  If an  affirmative  election  is made to
complete the well for production,  production casing is then generally  cemented
in the hole and completion operations are then commenced.

      "Development  costs" are costs incurred to drill,  equip, or obtain access
to proved  reserves.  They include costs of drilling and equipment  necessary to
get products to the point of sale and may entail on-site processing.

      "Exploration  costs"  are  costs  incurred,  either  before  or after  the
acquisition of a property,  to identify areas that may have potential  reserves,
to examine specific areas considered to have potential  reserves,  to drill test
wells,  and drill  exploratory  wells.  Exploratory  wells are wells  drilled in
unproven  areas.  The  identification  of properties and examination of specific
areas will typically include  geological and geophysical costs, also referred to
as G&G, which include topological studies, geographical and geophysical studies,
and costs to obtain access to properties  under study.  Depreciation  of support
equipment, and the costs of carrying unproved acreage, delay rentals, ad valorem
property taxes,  title defense costs,  and lease or land record  maintenance are
also classified as exploratory costs.

     "Farmout" involves an entity's  assignment of all or a part of its interest
in a property in exchange for the assignee's obligation to expend all or part of
the funds to drill and equip the property.

     "Future net revenues,  before income taxes" means an estimate of future net
revenues from a property at a specified date, after deducting  production and ad
valorem taxes,  future capital costs and operating  expenses,  before  deducting
income taxes. Future net revenues,  before income taxes, should not be construed
as being the fair market value of the property.

     "Future net revenues,  net of income taxes" means an estimate of future net
revenues from a property at a specified date, after deducting  production and ad
valorem taxes, future capital costs and operating expenses, net of income taxes.
Future net revenues,  net of income taxes,  should not be construed as being the
fair market value of the property.

     "Mcf"  means  thousand  cubic  feet, used in this report to refer to gas or
gaseous hydrocarbons.

     "MMcf"  means  million  cubic  feet, used in this report to refer to gas or
gaseous hydrocarbons.

     "MBbl" means  thousand  barrels,  used in  this  report  to refer  to crude
oil or other liquid hydrocarbons.

     "Gross" oil and gas wells or "gross"  acres is the total number of wells or
acres in which Regent has an interest.

     "Net"  oil and gas  wells or "net"  acres  are  determined  by  multiplying
"gross" wells or acres by Regent's interest in such wells or acres.

                                       24
<PAGE>
     "Oil and gas lease" or "Lease" means an agreement  between a mineral owner,
the lessor,  and a lessee  which  conveys the right to the lessee to explore for
and produce oil and gas from the leased lands. Oil and gas leases usually have a
primary term during  which the lessee must  establish  production  of oil and or
gas. If production is established within the primary term, the term of the lease
generally  continues in effect so long as production occurs on the lease. Leases
generally provide for a royalty to be paid to the lessor from the gross proceeds
from the sale of production.

     "Overpressured   reservoir"  are  reservoirs  subject  to  abnormally  high
pressure as a result of certain types of subsurface conditions.

     "Present  value of future net  revenues,  before income taxes" means future
net  revenues,  before  income  taxes,  discounted  at an annual  rate of 10% to
determine  their  "present  value." The present  value is shown to indicate  the
effect of time on the value of the revenue stream and should not be construed as
being the fair market value of the properties.

     "Present  value of future net  revenues,  net of income taxes" means future
net  revenues,  net of  income  taxes  discounted  at an  annual  rate of 10% to
determine  their  "present  value." The present  value is shown to indicate  the
effect of time on the value of the revenue stream and should not be construed as
being the fair market value of the properties.

     "Production  costs" means  operating  expenses and severance and ad valorem
taxes on oil and gas production.

     "Prospect" means a geologic anomaly which may contain hydrocarbons that has
been  identified  through the use of 3-D and/or 2-D seismic surveys and/or other
methods.

     "Proved oil and gas reserves"  are the  estimated  quantities of crude oil,
natural gas and  natural  gas liquids  which  geological  and  engineering  data
demonstrate  with  reasonable  certainty to be  recoverable in future years from
known reservoirs under existing economic and operating  conditions,  i.e. prices
and costs as of the date the estimate is made.  Prices include  consideration of
changes in existing prices provided only by contractual arrangements, but not on
escalations  based upon future  conditions.  Reservoirs are considered proved if
economic  producibility  is supported by either actual  production or conclusive
formation  test.  The area of a reservoir  considered  proved  includes (A) that
portion delineated by drilling and defined by gas-oil and/or oil-water contacts,
if any, and (B) the immediately  adjoining  portions not yet drilled,  but which
can  reasonably be judged as  economically  productive on the basis of available
geological and engineering data. In the absence of information on fluid contacts
the lowest known structural occurrence of hydrocarbons controls the lower proved
limit of the reservoir.

     "Proved  developed  oil and gas reserves" are reserves that can be expected
to be recovered  through  existing  wells with existing  equipment and operating
methods.  Additional  oil and gas reserves  expected to be obtained  through the
application  of  fluid  injection  or other  improved  recovery  techniques  for
supplementing  the natural forces and mechanisms of primary  recovery  should be
included as "proved developed reserves" only after testing by a pilot project or
after the  operation of an installed  program has confirmed  through  production
response that increased recovery will be achieved.

                                        25
<PAGE>
     "Proved undeveloped oil and gas reserves" are reserves that are expected to
be recovered from new wells on undrilled acreage, or from existing wells where a
relatively major expenditure is required for recompletion. Reserves on undrilled
acreage shall be limited to those drilling  units  offsetting  productive  units
that are  reasonably  certain of production  when drilled.  Proved  reserves for
other  undrilled  units can be claimed  only where it can be  demonstrated  with
certainty  that there is continuity of production  from the existing  productive
formation.  Under no  circumstances  should  estimates  for  proved  undeveloped
reserves  be  attributable  to any  acreage  for which an  application  of fluid
injection or other  improved  recovery  technique is  contemplated,  unless such
techniques  have been proved  effective  by actual  tests in the area and in the
same reservoir.

     "Reserve  target" means a geologic  anomaly which may contain  hydrocarbons
that has been  identified  through  the use of 3-D and 2-D  seismic  surveys and
or other methods.

     "Royalty  interest" is a right to oil,  gas, or other  minerals that is not
burdened  by the costs to develop or operate  the  related  property.  The basic
royalty interest is retained by the owner of mineral rights when his property is
leased for purposes of development.

     "Trend" means a geographical area where similar geological, geophysical, or
oil and gas reservoir and production characteristics may exist.

     "Seismic  option"  generally  means an agreement in which the mineral owner
grants  the right to acquire  seismic  data on the  subject  lands and grants an
option to acquire an oil and gas lease on the lands at a predetermined price.

     "2-D Seismic" means an advanced technology method by  which a cross-section
of the earth's subsurface is  created through the  interpretation  of reflecting
seismic data collected along a single source profile.

     "3-D Seismic" means an advanced  technology method  by which a three dimen-
sional image of the earth's subsurface is created through the  interpretation of
reflection  seismic data  collected  over a  surface grid.  3-D seismic  surveys
allow for a more  detailed understanding of the  subsurface than do conventional
surveys and  contribute  significantly  to a field's  appraisal, development and
production.

     "Working  interest"  is an  interest  in an oil  and gas  property  that is
burdened with the costs of development and operation of the property.

     "Workover" means operations on a producing well or an abandoned well to re-
store or increase production.

                                     26
<PAGE>
Item 3.  Quantitative and Qualitative Disclosures About Market Risk
-------  ----------------------------------------------------------

There have been no material changes in market risk from the information provided
in our  report on Form 10-K as  of December 31, 2009.  In the future, we will be
exposed to  market risk from changes in  oil and gas prices,  interest rates and
foreign currency exchange rates as discussed below in Risk Factors.

Item 4.  Controls and Procedures
-------  -----------------------

Evaluation of Disclosure Controls and Procedures

The Company's  principal  executive  and  financial  officers  have conducted an
evaluation of  the  effectiveness  of  the  Company's  disclosure  controls  and
procedures pursuant to  Rule 13a-15(b) under the Securities Exchange Act of 1934
as of the end of the period (the "Evaluation Date"). Based upon that evaluation,
the Company's principal executive and financial officers have concluded that, as
of the Evaluation Date, the Company's  disclosure controls  and  procedures were
effective in ensuring that  all  material  information  relating  to the Company
required to be filed in  this quarterly  report has been made known to them in a
timely manner.  The Company  believes  that a control system, no matter how well
designed and operated, cannot  provide absolute assurance that the objectives of
the control system are met, and no evaluation of controls  can provide  absolute
assurance  that all issues of control and instances of fraud, if any, within any
company have been detected.

Changes in Internal Control over Financial Reporting

No change in the Company's system of internal  control over financial  reporting
occurred during the most recent fiscal quarter that has materially affected,  or
is  reasonably  likely to materially  affect,  internal  control over  financial
reporting.
                           PART II. OTHER INFORMATION

Item 1.  Legal Proceedings.
-------  ------------------

The Company is not aware of any  pending claims or  assessments, that may have a
material  adverse  impact on our financial position or operations.  See  Note 12
in our Form 10-K as of December 31, 2009 for a discussion of prior proceedings.

Item 1A.  Risk Factors.
--------  -------------

The  discussion  in Part I, "Item 1A. Risk Factors." in  the Company's 2009 Form
10-K, of the risk factors which could materially affect the Company's  business,
or future results, should be carefully considered.  The risks described  in  the
Form  10-K are  not the only   risks  facing the Company.  Additional  risks and
uncertainties not currently known to the Company or that currently are deemed to
be immaterial  also  may  materially adversely  affect  the  Company's  business
condition or operating results, including, but not limited to, the following:

OUR COMPANY HAS A LIMITED OPERATING HISTORY.

Our limited operating history  makes it difficult  for us to evaluate our future
business  prospects  and make decisions  based on those estimates of  our future
performance.  Although our  management team has been engaged in technology deve-
lopment  for an  extended  period of time,  we did  not begin  operations of our
current business concept until recently. Therefore, it is difficult  to forecast
our future results  based upon our  historical data.  Reliance on the historical
results of our  acquisition targets  may not be representative of the results we
will achieve,  particularly in  our combined form.  Because of the uncertainties
related to our lack of  historical operations, we may be hindered in our ability
to anticipate and timely adapt  to increases or decreases in income or expenses.
If we make poor budgetary  decisions as a  result of unreliable historical data,
we could be less  profitable or incur losses, which may  result in a  decline in
our stock price.

                                       27
<PAGE>
COMPETITION FOR RENEWABLE ENERGY TECHNOLOGY AND NATURAL RESOURCES ARE FIERCE.

The worldwide  energy industry is  highly  fragmented and  we are competing with
numerous companies looking for renewable energy technologies and capital related
thereto.  We are one of the smallest energy technology development companies and
are an  infinitely  small participant in  the oil and  gas exploration business.
The presence of  competing   technology development  companies  will  impact our
ability to raise additional capital in order  to fund our technology programs if
investors  are of the view that investments in competitors  are more attractive.
We  will  also  be  competing  with  other  technology  companies  for available
resources,  including,  but  not  limited  to,  qualified  personnel, properties
suitable for exploration and development, and green energy technologies.

WE COULD BE IN AN EXTENDED GLOBAL ECONOMIC RECESSION.

The current global  economic and  financial  crisis could  lead  to an  extended
national  or global economic recession.   A slowdown in economic activity caused
by a recession  would likely reduce  national and  worldwide  demand for oil and
natural  gas and result in lower  commodity prices  for  long  periods  of time.
Prices for oil and natural gas have decreased  significantly from highs in 2008.
In the last eighteen months, oil  prices  have decreased by up to one half their
highest  prices and natural gas prices  have  decreased by more  than two thirds
during this time period.  Costs of exploration,  development and production have
not yet adjusted to current economic conditions or  in proportion to the reduced
product prices.  Prolonged,  substantial decreases in oil and natural gas prices
would  likely have a  material  adverse effect on  Regent's business,  financial
condition and results of operations,  could  further limit the  Company's access
to credit and could hinder its ability to satisfy its capital requirements.

CAPITAL AND CREDIT MARKETS VOLATILITY MAKE FUNDING UNCERTAIN.

Capital  and  credit  markets  have  experienced  unprecedented  volatility  and
disruption  during the  last  half  of 2008 and  continued  to be  unpredictable
through  2009 and into 2010.  Given the  current levels of market volatility and
disruption, the  availability of  funds from  those  markets has diminished very
substantially. Further, arising from concerns  about the  stability of financial
markets  generally  and  the  solvency of  borrowers  specifically, the  cost of
accessing the credit markets  has increased as many lenders have raised interest
rates, enacted tighter lending standards or  have  altogether  ceased to provide
funding  to  borrowers.  Accordingly, we  are evaluating  numerous  and  various
alternatives, such as  joint ventures with  third parties, or  sales of interest
in one or more of its properties.  Such transactions if undertaken, could result
in a reduction in  the  Company's operating  interests or require the Company to
relinquish  the right to  operate the property.  There can  be no assurance that
any such transactions  can be completed or that  such transactions  will satisfy
the Company's operating capital requirements.

Our Company has no  commitments  to obtain  any  additional  financing and there
can be no assurance that additional financing will be  available, when required,
on  favorable  terms to us.  The inability to  obtain additional financing could
have a material adverse effect on us, including  requiring us to curtail our oil
and gas  acquisition  and  development plans  of our  properties  and technology
development of our emerging energy technologies.  Any  additional  financing may
involve substantial dilution to the interests of our shareholders at that time.

                                       28
<PAGE>
A MAJORITY OF OUR OUTSTANDING COMMON STOCK IS CLOSELY HELD AND ILLIQUID.

Our  directors  and  executive officers collectively own most of our outstanding
voting  stock.  Accordingly,  these  stockholders,  as a group, will  be able to
control  the  outcome  of  stockholder  votes,  including  votes  concerning the
election  of directors, the adoption or amendment of  provisions in our Articles
of  Incorporation  and  our  Bylaws,  and  the  approval  of  mergers  and other
significant  corporate transactions.  These factors may also have  the effect of
delaying  or  preventing  a change in our  management or our voting control. Our
Articles of Incorporation do not provide for cumulative voting.

The liquidity of our common stock may be  adversely affected, and  purchasers of
our common stock  may have difficulty  selling our common stock, if  our  common
stock does not trade in a suitable trading market.  There is presently a limited
public market for our common stock, and  there is no assurance that a market for
our securities will develop.  It is likely that any  market for our common stock
will be highly  volatile  and that  trading in  any such market will be limited.
The trading price of our common stock could  be  subject to wide fluctuations in
response to  quarter-to-quarter  variations in our operating results, notices of
our drilling results and other events or factors.

WE DO NOT INTEND TO DECLARE DIVIDENDS IN THE FORESEEABLE FUTURE.

We have not paid any cash dividends on our common stock  since our inception and
we do not anticipate paying cash dividends in the  foreseeable future. We intend
to retain  our  earnings,  if  any,  to  provide  funds  for reinvestment in our
acquisition  and  exploration  activities.   Therefore,  we  do  not  anticipate
declaring or paying  dividends in the  foreseeable  future.  Further, payment of
dividends, if  any,  in  the  future  is  within the discretion of the  board of
directors and will depend on our earnings, if any, our  capital requirements and
financial condition and other relevant factors.

RISKS RELATED TO OIL AND GAS EXPLORATION AND DEVELOPMENT ARE SUBSTANTIAL.
-------------------------------------------------------------------------

OUR PLANS TO RE-ENTER OIL AND GAS PROPERTIES HAS INHERENT RISKS.

We will  own or lease  properties that for many years have produced oil and gas.
It is not uncommon for such  properties to  be contaminated  with  hydrocarbons.
Although we or  previous owners  of these interests may have  used operating and
disposal  practices that were standard in the industry at the time, hydrocarbons
or other wastes may have been disposed of or released on or under the properties
or on or under other locations  where such wastes  have been taken for disposal.
These properties  may be subject to  federal or  state  requirements  that could
require us to remove any the wastes or to remediate the resulting contamination.
In addition to properties that we operate, we  have interests in many properties
which are operated by third parties over whom we have limited control.  Notwith-
standing our lack of control  over properties operated by others, the failure of
the previous owners or operators to comply with applicable environmental regula-
tions may, in certain circumstances, adversely impact us.

                                       29
<PAGE>
EXPLORATORY DRILLING IS A SPECULATIVE ACTIVITY THAT MAY FAIL COMMERCIALLY.

Drilling  activities  are subject  to many  risks, including  the  risk  that no
commercially productive  oil or gas reservoirs  will be  encountered.  There can
be no assurance that new wells drilled by us  will be productive or that we will
recover  all or any portion  of our  investment.  Drilling for  oil and  gas may
involve unprofitable efforts, not only  from dry wells, but also from wells that
are productive but do not  produce sufficient net  revenues to  return  a profit
after drilling, operating and other costs.  The cost of drilling, completing and
operating  wells is often  uncertain.  Our drilling operations may be curtailed,
delayed or  canceled  as a result of a  variety of  factors,  many of  which are
beyond  our  control, including  economic conditions, mechanical  problems, high
pressure or irregularities  in  formations, title  problems, weather conditions,
compliance with  governmental  requirements  and  shortages in  or delays in the
delivery of  equipment and  services.  In  today's  environment, shortages  make
drilling rigs, labor and services difficult to obtain and could  cause delays or
inability  to proceed  with our drilling and  development plans.  Such equipment
shortages and  delays sometimes  involve  drilling  rigs where inclement weather
prohibits the  movement of land rigs  causing a high demand for  rigs by a large
number of companies during a  relatively short period of time.  Regent's  future
drilling activities may not be successful.  Lack of drilling success  could have
a material adverse effect on our financial condition and results of operations.

OIL AND GAS OPERATIONS ARE SUBJECT TO HAZARDS.

Our operations are also  subject to all the  hazards and risks normally incident
to the  development,  exploitation,  production and  transportation of, and  the
exploration for, oil and natural gas, including  unusual or unexpected  geologic
formations,  pressures, down  hole fires, mechanical failures, blowouts,  leaks,
explosions, uncontrollable  flows of oil,  gas or well  fluids and pollution and
other environmental risks.  These hazards could result in  substantial losses to
us due to injury and loss of life, severe damage to and destruction  of property
and  equipment,  pollution and  other  environmental  damage and  suspension  of
operations.  We participate in insurance coverage maintained  by the operator of
its  wells, although  there can be  no  assurances  that such  coverage  will be
sufficient to prevent a material adverse effect to us in such events.

WE NEED CAPITAL TO DEVELOP OUR PROVED RESERVES AND TO PURSUE THE ACQUISITION OF
PRODUCING OIL AND GAS PROPERTIES AND LEASES.

The vast majority of  our oil and natural gas reserves  are classified as proved
reserves.  Recovery of the Company's  future  proved  undeveloped  reserves will
require significant  capital expenditures as will the pursuit of the acquisition
of producing oil and gas properties and leases.  Regent's  management estimates,
but can make no guarantee, that our financing sources will be sufficient to fund
our planned development activities or that development activities will be either
successful or in  accordance  with our schedule.  Additionally, any  significant
decrease in  oil and  gas  prices or  any  significant  increase  in the cost of
development  could  result in a  significant  reduction  in the  number of wells
reworked and/or drilled.  No assurance can be  given that any wells will produce
oil or gas in commercially profitable quantities.

                                       30
<PAGE>
WE ARE SUBJECT TO RISKS UNDER THE CURRENT GOVERNMENT PROPOSED BUDGET.

The Obama  administration has  recently  set forth  budget  proposals  which  if
passed, would significantly curtail our  ability to  attract investors and raise
capital.  Proposed changes in the  federal income tax laws which would eliminate
or reduce the percentage  depletion deduction and   the deduction for intangible
drilling and  development costs for  small independent  producers, will  greatly
reduce the investment capital available to those in the industry  as well as our
Company.  An extended  time to expense  seismic  costs will also have an adverse
effect on our ability to explore and find new reserves.

WE ARE SUBJECT TO VARIOUS OPERATING AND OTHER CASUALTY RISKS.

Our oil and gas business involves a variety of  operating  risks, including, but
not limited to, unexpected  formations  or  pressures,  uncontrollable  flows of
oil, gas, brine  or  well  fluids into  the environment  (including  groundwater
contamination), blowouts,  fires, explosions, pollution and  other risks, any of
which could result in personal injuries, loss of life, damage to  properties and
substantial losses.  Although  we carry  insurance at levels that we believe are
reasonable, we  are  not  fully insured  against  all risks.  We  do  not  carry
business interruption insurance.  Losses and liabilities  arising from uninsured
or under-insured  events could have a material  adverse effect on  our financial
condition and operations.

We plan  to increase to some extent our development and, to a lesser extent, our
exploration activities.  Drilling of oil and gas  reserves involve a high degree
of risk that no commercial production will be found and/or that  production will
be insufficient to recover drilling and completion costs.  The cost of drilling,
completing and operating wells is  often uncertain.  Our drilling operations may
be  curtailed, delayed or  canceled as a  result of  numerous factors, including
title  problems, weather conditions,  compliance with governmental  requirements
and shortages or delays in the  delivery  of equipment.  Furthermore, completion
of a well does not assure a profit  on the investment or a recovery of drilling,
completion and operating costs.

WE ARE SUBJECT TO CERTAIN TITLE RISKS.

Our  Company  employees  and contract land  professionals  have  reviewed  title
records or other  title review  materials  relating to  substantially all of our
producing  properties.   The  title  investigation  performed  by  us  prior  to
acquiring  undeveloped  properties  is  thorough, but  less rigorous  than  that
conducted prior to  drilling, consistent with industry standards.  We believe we
have  satisfactory  title to all our  producing  properties in  accordance  with
standards generally  accepted in the oil  and gas industry.  Our  properties are
subject to customary royalty interests, liens incident to operating  agreements,
liens for  current taxes  and other burdens, which we  believe do not materially
interfere with the use of or  affect the value of such properties.

OIL AND NATURAL GAS PRICES FLUCTUATION MAY ADVERSELY IMPACT OUR RESULTS.

Our revenues, profitability, and the  book  value of our  oil and gas properties
are  substantially dependent upon prevailing prices of, and demand  for, oil and
gas and the  costs of  acquiring,  finding, developing, and  producing reserves.
Our ability to  obtain borrowing capacity, to repay future  indebtedness, and to
obtain additional  capital on favorable terms  is also  primarily dependent upon
oil and gas prices which historically  have been subject to wide fluctuations in
response to: (i) relatively  minor changes in the supply of, and demand for, oil
and  gas; (ii) market  uncertainty; and (iii)  a variety of  additional factors,
all of which are beyond our control.  These factors include domestic and foreign
political conditions, the price  and availability of  domestic and  imported oil
and gas, the  level  of consumer  and industrial  demand, weather, domestic, and
foreign  government relations, the price and  availability of  alternative fuels
and  overall  economic  conditions.  Also, the  marketability of  our production
depends in part upon  the availability, proximity and capacity of gathering sys-
tems, regulated pipelines and processing facilities.

                                       31
<PAGE>
WE MAY BE RESPONSIBLE FOR ABANDONMENT COSTS OF OIL AND GAS PROPERTIES.

We are responsible for payment of plugging and abandonment costs  on its oil and
gas properties  pro rata to our  working interest.  Based on  our experience, we
anticipate that in most cases,  the  ultimate  aggregate salvage  value of lease
and  well equipment  located on our  properties  should  equal  to the  costs of
abandoning such properties. There can be no  assurance, however, that we will be
successful in avoiding  additional  expenses in connection  with the abandonment
of any of our properties.  In addition,  abandonment costs  and their timing may
change  due  to many  factors, including  actual  production  results, inflation
rates and changes in environmental laws and regulations.

GENERAL RISKS THAT IMPACT THE OIL AND GAS INDUSTRY.
---------------------------------------------------

WE ARE SUBJECT TO VARIOUS GOVERNMENTAL REGULATIONS.

Our operations  are affected  from time to time in  varying degrees by political
developments and federal, state and local laws  and regulations.  In particular,
oil  and gas production  related operations  are or  have been subject  to price
controls, taxes  and other laws  and  regulations relating  to the  oil  and gas
industry.   Failure  to comply  with  such  laws  and regulations  can result in
substantial penalties. The regulatory burden on the oil and natural gas industry
increases  our cost of doing  business and  affects our profitability.  Although
we believe we will work  in substantial compliance  with all applicable laws and
regulations, because  such laws and  regulations are frequently amended or rein-
terpreted, we are unable to predict the future cost or  impact of complying with
such laws and regulations.

FEDERAL REGULATION OF NATURAL GAS IS SIGNIFICANT AND COMPLEX.

Sales of natural gas by  us are not regulated  and are generally  made at market
prices.  However, the  Federal Energy  Regulatory Commission ("FERC")  regulates
interstate  natural gas  transportation rates and service conditions, which will
affect the  marketing of  natural gas  produced  by us, as well  as the revenues
received by us for sales of such production.

Since the mid-1980's,  the FERC has  issued a series  of orders,  culminating in
Order Nos. 636, 636-A  and 636-B ("Order 636"), that have  significantly altered
the  marketing  and  transportation of  natural gas.  FERC Order 636  mandated a
fundamental  restructuring  of  interstate  pipeline  sales  and  transportation
service,  including the  unbundling by  the  interstate  pipelines of the  sale,
transportation,  storage  and other  components of the  city-gate sales services
that such pipelines previously performed.  One of the FERC's purposes in issuing
orders was to increase competition.  While any  additional  FERC action on these
matters would  affect us only indirectly,  these policy statements  and proposed
rules and new changes are intended to further enhance competition in natural gas
markets.  We cannot predict what direction the  FERC will take on these matters,
nor  can we predict whether the FERC's actions  will achieve  its stated goal of
increasing  competition in natural gas markets.  However, we do not believe that
we will be treated materially differently  than other natural gas  producers and
marketers with which we will compete.

                                       32
<PAGE>
FEDERAL REGULATION OF OIL AND PRODUCT TRANSPORTATION CAN IMPACT PRICES.

The price we receive from the sale of oil is affected  by the cost of transport-
ing such  products to market.  Effective  January 1, 1995, the  FERC implemented
regulations  establishing an  indexing system for  transportation rates  for oil
pipelines  which would index such  rates to inflation.  These  regulations could
increase the cost of transporting oil by interstate pipelines or reduce wellhead
prices for oil.

COMPLIANCE WITH THE TEXAS RAILROAD COMMISSION REGULATIONS IS COSTLY.

The State of Texas and many other states regulate oil and gas operations includ-
ing permits for drilling, field operations, bonds and  reports concerning opera-
tions and impose other  requirements relating to the exploration for and produc-
tion of oil and gas.  Texas  also has statutes or regulations addressing conser-
vation matters, including  provisions for the unitization or pooling of oil  and
gas properties, the establishment of maximum rates of  production from wells and
the  regulation of spacing, and abandonment of such wells.

WE ARE SUBJECT TO VARIOUS ENVIRONMENTAL RISKS AND COSTS.
-------------------------------------------------------

ENVIRONMENTAL REGULATION SERIOUSLY IMPACTS OIL AND GAS OPERATIONS.

Our operations and properties will be subject to extensive and changing federal,
state and  local laws  and regulations  relating  to  environmental  protection,
including  the generation,  storage, handling and  transportation of oil and gas
and the discharge of  materials into the environment, and relating to safety and
health.  The recent  trend in environmental legislation and regulation generally
is toward  stricter standards, and this  trend will likely continue.  These laws
and regulations  may require the acquisition of a permit  or other authorization
before  construction or  drilling commences  and  for certain  other activities;
limit or prohibit  construction, drilling and other activities  on certain lands
lying  within  wilderness  and  other  protected  areas; and  impose substantial
liabilities  for pollution  resulting from our operations.  The permits required
for our various  operations are subject  to revocation, modification and renewal
by issuing  authorities.  Governmental  authorities have  the  power  to enforce
compliance  with  their  regulations,  and  violations  are  subject  to  fines,
penalties  or injunctions.  In the opinion of  management, we are in substantial
compliance  with current  applicable environmental laws  and regulations, and we
have no material  commitments for capital  expenditures to  comply with existing
environmental  requirements.  Nevertheless,  changes  in existing  environmental
laws and  regulations or in  interpretations thereof  could  have a  significant
impact  on us.  The  impact of such  changes, however, would  not likely  be any
more burdensome to us than to any other similarly situated oil and gas company.

THE SUPERFUND LAWS REMAIN ONEROUS.

The federal  Comprehensive  Environmental Response, Compensation,  and Liability
Act ("CERCLA"), also known as the "Superfund" law, and similar state laws impose
liability, without  regard to fault or the legality of  the original conduct, on
certain  classes of  persons  that are  considered  to have  contributed  to the
release of a "hazardous substance"  into the environment.  These persons include
the owner or  operator of the  disposal site or sites where the release occurred
and companies that  disposed or arranged for the disposal of the hazardous waste
and substances found at the site.  Persons who are  or were responsible  for re-
leases of hazardous  substances under CERCLA may be subject to joint and several
liability for the costs of  cleaning up the hazardous substances  that have been
released into the environment and for damages to natural resources. Furthermore,
neighboring  landowners and  other third parties  may file  claims for  personal
injury and property damage allegedly caused by the hazardous substances released
into the environment.

                                       33
<PAGE>
THE EPA IS INCREASING REGULATION OF OIL AND GAS OPERATIONS.

We will  generate typical  oil and gas  field wastes, including hazardous wastes
that are  subject to  the Federal Resources  Conservation  and Recovery  Act and
comparable  state statutes.  The  United States Environmental Protection  Agency
and various  state agencies  have limited the  approved methods of  disposal for
certain  hazardous and non-hazardous wastes.  Furthermore, some wastes generated
by our oil and gas operations  that are currently exempt from regulation  may in
the future be designated as "hazardous wastes", and therefore be subject to more
rigorous and costly operating and disposal requirements.

Also, the Oil Pollution Act ("OPA") imposes a variety of requirements on respon-
sible parties for onshore and offshore production facilities and vessels related
to the prevention of oil spills and liability for damages  resulting  from  such
spills  in waters of the  United States.   The "responsible  party" includes the
owner or  operator of an onshore  facility or vessel  or the lessee or permittee
of, or the  holder of a right of use and easement for, the area where an onshore
facility  is located.  OPA assigns liability to  each responsible party  for oil
spill removal costs and a variety of public and private damages from oil spills.
Few defenses  exist to the  liability for  oil spills  imposed by OPA.  OPA also
imposes  financial responsibility requirements.  Failure  to comply with ongoing
requirements or  inadequate cooperation in a spill event may subject a responsi-
ble party to civil or criminal enforcement actions.

Item 2.  Unregistered Sales of Equity Securities and Use of Proceeds.
------   -----------------------------------------------------------

         Unless otherwise noted, the issuances noted below are all considered
         exempt from registration by reason of Section 4(2) of the Securities
         Act of 1933, as amended, and/or Rule 506 as promulgated under Reg D.

         On September 29, 2010, we entered into a Property Transfer Agreement
         with the CEO and  Signature Investor Group, LC, pursuant to which we
         acquired  certain oil and gas  interests in exchange  for 13,500,000
         shares newly issued restricted common stock.


Item 3.  Defaults Upon Senior Securities.
-------  --------------------------------
         None.

Item 4.  Submission of Matters to a Vote of Security Holders.
-------  ----------------------------------------------------

         None.

Item 5.  Other Information.
-------  ------------------

         None.

                                       34
<PAGE>
Item 6.  Exhibits and Reports on Form 8-K.
-------  ---------------------------------

         (a) Exhibits

         Exhibit 31.1  Certification of C.E.O. and Principal Accounting Officer
                       Pursuant to Section 302 of the Sarbanes-Oxley Act of
                       2002.

         Exhibit 32.1  Certification of C.E.O. and Principal Accounting Officer
                       Pursuant to 18 U.S.C. Section 1350, as  Adopted Pursuant
                       to Section 906 of the Sarbanes-Oxley Act of 2002

         (b) Reports on Form 8-K

                       The Registrant reported the hiring of the General Manager
                       for the Energy Technology Division on August 26, 2010.

                       The Registrant reported the hiring of the General Manager
                       of the Natural Resources Division on September 14, 2010.

                       The Registrant reported the agreement to exchange stock
                       for oil and gas properties on September 17, 2010.

                       The Registrant reported the termination of the agreement
                       with Healthcare of Today, Inc. for the purchase of the
                       MacuCLEAR Preferred Stock on September 29, 2010.

                       The Registrant reported the closing of the Property
                       Transfer Agreement, effective September 29, 2010, on
                       October 8, 2010.

                                      35

<PAGE>
                                   SIGNATURE


In accordance with the requirements of the Exchange Act of 1934, the Registrant
has duly caused this report to be signed on its behalf by the undersigned
thereunto duly authorized.






Date:  November 10, 2010            REGENT TECHNOLOGIES, INC.
                                          (Registrant)

                           By: /s/ David A. Nelson
                                   ---------------------------------------
                                   David A. Nelson, Chief Executive Officer
                                   (Principal Financial and Accounting Officer)

                                      36
<PAGE>




                                  EXHIBIT INDEX
                                  -------------

Exhibit No.                             Description
-----------                             -----------

2.1 	  Property Transfer Agreement executed September 30, 2010 between the
          Company and David A. Nelson and Signature Investor Group, LC. - Filed
          herewith.

31        Certification required by Rule 13a-14(a) under the Securities Exchange
          Act of 1934 - Filed herewith.

32        Certification required pursuant to 18 U.S.C. Section 1350 - Filed
          herewith.


                                      37
<PAGE>