UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

FORM 10-Q

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

FORM 10-Q

(Mark One)

[ X ]

Quarterly report under Section 13 or 15(d) of the Securities Exchange Act of 1934

For the quarterly period ended ~~March~~June 3130, 2009

[ ]	Transition report under Section 13 or 15(d) of the Securities Exchange Act of 1934

For the transition period from ______________ to _______________

Commission file number 033-15528

MONUMENT RESOURCES, INC.

(Exact name of Registrant as Specified in its ~~Charter~~charter)

Colorado	84-1028449
(State or Other Jurisdiction of Incorporation or Organization)	(I.R.S. Employer Identification No.)
(State or other jurisdiction of	(I.R.S. Employer Identification No.)
incorporation or organization)

2050 South Oneida Street, Suite 106, Denver, Colorado 80224

(Address of ~~Principal~~principal ~~Executive~~executive ~~Offices~~offices, ~~Including~~including ~~Zip~~zip ~~Code~~code)

(303) 692-9468

(Registrant’s telephone ~~Telephone Number~~number, ~~Including~~including ~~Area~~area ~~Code~~code)

Indicate by check mark whether the registrant (1) has filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the past 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 has submitted electronically and posted on its corporate Web site, if any, every Interactive Data File required to be submitted and posted pursuant to Rule 405 of Regulation S-T during the preceding 12 months (or for such shorter period that the registrant was required to submit and post such files).

Yes ~~____~~ ___ No __X___

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

Large accelerated filer [ ]	Accelerated filer [ ]
Non-accelerated filer [ ] (Do not check if a smaller reporting company)	Smaller reporting company [ X ]

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

Yes ~~_____~~ ___ No X __X___

State the number of shares outstanding of each of the issuer’s classes of common equity, as of the latest practicable date: 7,869,000 shares of common stock were outstanding at ~~May~~August 12, 2009.

MONUMENT RESOURCES, INC. AND SUBSIDIARY

INDEX

		Page Number
PART I.	FINANCIAL INFORMATION
Item 1.	Condensed Consolidated Balance Sheets as of ~~March~~June 3130, 2009 and September 30, 2008	2
	Condensed Consolidated Statements of Operations for the Three Months and Six Months ended March 31, 2009 and 2008	4
	Condensed Consolidated Statements of Operations for the Three Months and Nine Months ended June 30, 2009 and 2008	4
	Condensed Consolidated Statements of Cash Flows for the Six Months ended March 31, 2009 and 2008	5
	Condensed Consolidated Statements of Cash Flows for the Nine Months ended June 30, 2009 and 2008	5
	Notes to Condensed Consolidated Financial Statements	6
Item 2.	Management’s Discussion and Analysis of Financial Condition and Results of Operations	1213
Item 3.	Quantitative and Qualitative Disclosures about Market Risk.	1517
Item 4.	Controls and Procedures	1617
PART II.	OTHER INFORMATION	1718
Item 1.	Legal Proceedings	1718
Item 1A.	Risk Factors	1718
Item 2.	Unregistered Sales of Equity Securities and Use of Proceeds	1718
Item 3.	Defaults Upon Senior Securities	1718
Item 4.	Submission of Matters to a Vote of Security Holders	1718
Item 5.	Other Information	1718
Item 6.	Exhibits	1718
	Signatures	1819
	Exhibit Index	1920

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Item 1. Financial Statements.

MONUMENT RESOURCES, INC. AND SUBSIDIARY

CONDENSED CONSOLIDATED BALANCE SHEETS

		March 31,			September 30,
			June 30,			September 30,
		~~2009~~	2009		~~2008~~	2008
ASSETS		(Unaudited)
			(Unaudited)
Current assets
ASSETS
Cash and cash equivalents		$	107,114		$	204,613
Current assets
Marketable securities available-for-sale			495,533			666,949
	Cash and cash equivalents		$	10,629		$	204,613
Accounts receivable			17,633			45,471
	Marketable securities available-for-sale			494,719			666,949
Prepaid expenses and other assets			3,147			4,829
	Accounts receivable			21,127			45,471
Total current assets			623,427			921,862
	Prepaid expenses and other assets			1,787			4,829
Proved and unproved oil and gas
Total current assets				528,262			921,862
properties, successful efforts method
Proved and unproved oil and gas properties, successful efforts method net of accumulated depletion				273,279			667,150
net of accumulated depletion			265,700			667,150
Property and equipment:
Property and equipment:
	Gas pipeline, net of
Gas pipeline, net of
	accumulated depreciation			-			182,105
accumulated depreciation			-			182,105
	Property and equipment, net of
Property and equipment, net of
	accumulated depreciation			436,391			478,731
accumulated depreciation			451,404			478,731
Net property, equipment and pipeline				436,391			660,836
Net property, equipment and pipeline			451,404			660,836
Total assets			$	1,237,932		$	2,249,848
Total assets		$	1,340,531		$	2,249,848

See Notes to Condensed Consolidated Financial Statements.

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MONUMENT RESOURCES, INC. AND SUBSIDIARY

CONDENSED CONSOLIDATED BALANCE SHEETS (CONTINUED)

	March 31,			September 30,
	June 30,			September 30,
	2009			2008
LIABILITIES AND STOCKHOLDERS’ EQUITY	(Unaudited)
Current liabilities
Accounts payable and accrued expenses	$	2225,~~349~~137		$	64,145
Asset retirement obligation		~~106~~108,~~492~~066			103,343
Total liabilities		~~128~~133,~~841~~203			167,488
Stockholders’ equity:
Preferred Stock, no par value, authorized
1,000,000 shares; none issued		-			-
Common Stock, no par value, authorized		~~3,973,109~~			~~3,938,149~~
500,000,000; 7,869,000 and 7,719,000
issued and outstanding at March 31, 2009
issued and outstanding at June 30, 2009
and September 30, 2008 respectively		3,975,589			3,938,149
Accumulated (deficit)		(2,~~756~~865,~~952~~579	)		(1,847,801	)
Unrealized gain (loss) on investment in securities		(45,~~467~~281	)		(7,988	)
Total stockholders’ equity		1,~~211~~104,~~690~~729			2,082,360
Total liabilities and stockholders’ equity	$	1,~~340~~237,~~531~~932		$	2,249,848

See Notes to Condensed Consolidated Financial Statements.

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MONUMENT RESOURCES, INC. AND SUBSIDIARY

CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS

(UNAUDITED)

	Three Months						~~Six~~Nine Months
	Ended March 31,						Ended March 31,
	Ended June30,						Ended June 30,
	2009			2008			2009			2008
Revenue
Oil and gas sales	$	2819,~~735~~936		$	76110,~~433~~346		$	6484,~~183~~119		$	~~111~~221,~~165~~511
Pipeline income		2421,~~262~~846			24,~~555~~272			5072,~~228~~074			3458,~~721~~993
Total revenue		5241,~~997~~782			~~100~~134,~~988~~618			~~114~~156,~~411~~193			~~145~~280,~~886~~504
Expenses
Oil and gas operating expense		25,~~652~~788			1316,~~346~~673			4773,~~669~~457			2642,~~003~~676
Pipeline operating expense		5339,~~213~~744			3742,~~947~~676			94134,~~697~~441			74116,~~282~~958
Impairment of oil and gas and
pipeline assets		~~699,688~~-			-			699,688			-
General and administrative		7465,~~235~~902			5378,055			~~151~~217,~~388~~290			~~113~~191,~~563~~618
Depletion, depreciation and amortization		1023,~~345~~201			2434,~~778~~177			4265,~~437~~638			4882,~~286~~463
Total operating expenses		~~863~~154,~~133~~635			~~129~~171,~~126~~581			1,~~035~~190,~~879~~514			~~262~~433,~~134~~715
Net income (loss) from operations		(~~810~~112,~~136~~853	)		(2836,~~138~~963	)		(~~921~~1,~~468~~034,321	)		(~~116~~153,~~248~~211	)
Other income and (expense)
Gain on sale of securities		63			-			63			-
Gain on sale of securities-		-			-			63			-
Interest income and other		4,~~693~~226			57,~~309~~530			1216,~~254~~480			1421,~~019~~549
Net income (loss)	$	(~~805~~108,~~380~~627	)	$	(2229,~~829~~433	)	$	$(~~909~~1,~~151~~017,778	)		(~~102~~131,~~229~~662	)
Basic and diluted (loss) income per common share	$	(.1001	)	$	(.00	)	$	(.1213	)	$	(.02	)
Basic and dilutive weighted average number of shares outstanding		7,869,000			6,031,088			7,793,176			5,673,098
Basic and dilutive weighted average number of
shares outstanding		7,869,000			7,719,000			7,768,451			6,352,577

See Notes to Condensed Consolidated Financial Statements.

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MONUMENT RESOURCES, INC. AND SUBSIDIARY

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS

(UNAUDITED)

	Six Months Ended March 31,
	Nine Months Ended June 30,
	2009			2008
Cash flows from operating activities:
Net loss	$	(~~909~~1,~~151~~017,778	)	$	(~~102~~131,~~229~~662	)
Adjustment to reconcile net loss to net cash
used in operating activities:
Depreciation, depletion and amortization		4265,~~437~~638			4882,~~286~~463
Impairment of oil and gas and pipeline assets		699,688			-
Stock compensation		47,~~960~~440			-
Changes in operating assets and liabilities:
Decrease in prepaid expenses
and other assets		13,~~682~~042			1016,~~999~~466
(Increase) decrease in accounts and
Decrease (increase) in accounts and
other receivables		2724,~~838~~344			(1921,~~414~~368	)
(Decrease) in accounts payable
and accrued expenses		(4139,~~796~~008	)		(72,~~264~~173	)
Net cash flows (used in) operations		(~~174~~256,~~342~~634	)		(6956,~~622~~274	)
Cash flows from investing activities:
Proceeds from sales of marketable securities		674,937			199,999
Purchase marketable securities		(500,000	)		-(500,000	)
Additions to oil and gas properties		(6978,~~422~~677	)		-(23,547	)
Additions to equipment		(2833,~~672~~610	)		(78180,~~297~~842	)
Net cash flows provided by investing activities		7662,~~843~~650			~~121~~(504,~~702~~390	)
Cash flows from financing activities:
Proceeds from sale of common stock in private
placement memorandum		-			600,000
Net cash flow provided by financing activities		-			600,000
Net (decrease) increase in cash and cash equivalents		(97193,~~499~~984	)		~~652~~39,~~080~~336
Cash and cash equivalents at beginning of period		204,613			213,808
Cash and cash equivalents at end of period	$	~~107~~10,~~114~~629		$	~~865~~253,~~888~~144
Schedule of Non-cash Investing Activities
Stock issued for purchase of royalty interest	$	30,000		$	-
Decrease in unrealized loss
on securities available for sale		32,~~522~~707			91,~~635~~782
Total non-cash investing activities	$	3332,~~522~~707		$	91,~~635~~782

See Notes to Condensed Consolidated Financial Statements

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MONUMENT RESOURCES, INC. AND SUBSIDIARY

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

NOTE 1 -- ORGANIZATION AND SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES

THE COMPANY

Monument Resources, Inc, (the “Company”) was organized under the laws of the State of Colorado on October 1, 1984. We are in the business of acquiring and brokering mineral and oil and gas properties and exploring, developing, and selling production from our oil and gas properties. Our oil and gas properties are in Leavenworth County, Kansas. We also operate a gas pipeline in conjunction with our Leavenworth gas wells.

We have a substantial investment in oil and gas properties. We may not have sufficient capital to fully develop some of our gas properties, which would require additional investment. We have in the past relied on joint venture partners and the private placement of common stock to supply most of the funds needed to explore or develop our properties, and may also rely on such partners for similar funding in the future. Our ability to obtain outside funding may be critical to our development efforts of some of our properties.

On August 12, 2009, we obtained approval from our shareholders to attempt to sell our Kansas properties and pipeline. See Part II, Item 4 hereof for further information.

BASIS OF PRESENTATION

The accompanying condensed consolidated financial statements are unaudited. However, in the opinion of management, the accompanying condensed consolidated financial statements reflect all adjustments are necessary for fair presentation. Interim results of operations are not necessarily indicative of results for subsequent interim periods or the remainder of the year. These financial statements should be read in conjunction with our Annual Report on Form 10-K for the year ended September 30, 2008.

Except for the historical information contained in this Form 10-Q, this Report contains forward-looking statements that involve risks and uncertainties. Our actual results could differ materially from those discussed in this Report. Factors that could cause or contribute to such differences include, but are not limited to, those discussed in this Report and in our Annual Report on Form 10-K for the year ended September 30, 2008.

CONSOLIDATION

The accompanying condensed consolidated financial statements include the accounts of our Company, and our wholly owned Kansas subsidiary, COG Transmission Corporation. All inter-company transactions and balances have been eliminated in consolidation.

REVENUE RECOGNITION

Sales of oil and gas production and pipeline income are recognized at the time of delivery of the product to the purchaser.

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EARNINGS PER SHARE

We have adopted Statement of Financial Accounting Standards (“SFAS”) No. 128, addressing earnings per share. SFAS No. 128 established the methodology of calculating basic earnings per share and diluted earnings per share. The calculations differ by adding any instruments convertible to common stock (such as stock options, warrants, and convertible preferred stock) to weighted average shares outstanding when computing diluted earnings per share. As of ~~March~~June 3130, 2009 all warrants outstanding were ~~excluded~~ excluded from earnings per share as their effects would be anti-dilutive.

OIL AND GAS PROPERTIES

We follow the successful efforts method of accounting for our oil and gas activities. Under this method, costs associated with the acquisition, drilling and equipping of successful exploratory and development wells are capitalized. Geological and geophysical costs, delay rentals and drilling costs of unsuccessful exploratory wells are charged to expense as incurred. Depletion and depreciation of the capitalized costs for producing oil and gas properties are provided by the unit-of-production method based on proved oil and gas reserves. Cash received for partial conveyances of property interests is treated as a recovery of cost and no gain or loss is recognized. Undeveloped and unproved properties are periodically assessed for possible impairment due to un-recoverability of costs invested. Developed and proved properties are assessed quarterly under the accounting rules of SFAS No. 144, “Accounting for the Impairment and Disposal of Long-Lived Assets”. This impairment is a non-cash charge to earnings. If required, it reduces earnings and impacts shareholders’ equity in the period of occurrence and results in lower depreciation and depletion in future periods. The impairment may not be reversed in future periods, even though higher oil and gas prices may subsequently increase the recoverability of costs invested. As of March 31, 2009 natural gas prices were significantly lower than at previous measurement dates. As a result, we recorded an impairment of oil and gas and pipeline segments of $699,688 ~~for~~which ~~the three~~is ~~month~~reflected ~~and~~in ~~six~~the nine month period ending ~~March~~June 3130, 2009 as compared to no ~~impairment~~ impairment expense during the same ~~periods~~period ended ~~March~~June 3130, 2008.

Given the current market for natural gas, it is conceivable that if natural gas prices continue to stay at these low levels, it will be necessary to recognize further impairment expenses during future reporting periods as required by SFAS No. 144. We will continue to evaluate our oil and gas properties for such impairment on a quarterly basis. No further impairment was deemed necessary for the three month period ended June 30, 2009.

INVESTMENT IN SECURITIES

We follow SFAS No. 115, “Accounting for Certain Investments in Debt and Equity Securities,” in accounting for our security investments. In accordance with SFAS No. 115, our investment in securities has been classified as available-for-sale because they are being held for an indefinite period of time. Under the available-for-sale classification, the securities are recorded as an asset at current market value on the balance sheet with an equal amount representing unrealized gains and losses recorded as a component of stockholders’ equity. The current market value is derived from market quotations as of the end of each quarter. At the time of sale, a gain or loss is recognized in the statement of operations using the cost basis of securities sold as determined by specific identification.

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FAIR VALUE OF FINANCIAL INSTRUMENTS

Our financial instruments consist of cash and cash equivalents, accounts receivable and accounts payable. The fair market value of these financial instruments approximates or is equal to the book value.

In the first quarter of fiscal year 2009, we adopted Statement of Financial Accounting Standard (SFAS) No. 157, “Fair Value Measurement” (SFAS No. 157) as amended by FASB Statement of Position (FSP) FAS 157-1 and FSP FAS 157-3. SFAS No. 157 defines fair value, establishes a framework for measuring fair value, and enhances fair value measurement disclosure. FSP FAS 157-3 delays, until the first quarter of fiscal year 2010, the effective date for SFAS 157 for all non-financial assets and non-financial liabilities, except those that are recognized or disclosed at fair value in the financial statements on a recurring basis (at least annually).

The following table provides information regarding the source of data used by us to develop fair value measurements:

Description	~~March~~June 3130, 2009		Quoted Prices in Active Markets for Identical Assets (Level 1)		Significant ~~Other~~other Observable Inputs (Level 2)	Significant Unobservable Inputs (Level 3)
Trading Securities	$	~~495~~494,~~533~~719	$	~~495~~494,~~533~~719
Total	$	~~495~~494,~~533~~719	$	~~495~~494,~~533~~719

COMPREHENSIVE INCOME

We have adopted SFAS No. 130, “Reporting Comprehensive Income”, which establishes standards for reporting comprehensive income. This pronouncement requires that all items recognized under accounting standards as components of comprehensive income, as defined in the pronouncement, be reported in a financial statement that is displayed with the same prominence as other financial statements. Comprehensive income includes changes in equity during a period, except those resulting from investments by owners and distributions to owners. Under comprehensive income, we report unrealized gains and losses on investments in debt and equity securities as changes in equity. (See Note 6.)

ASSET RETIREMENT OBLIGATIONS

We have adopted SFAS No. 143, “Accounting for Asset Retirement Obligations”. SFAS No. 143 addresses financial accounting and reporting for obligations associated with the retirement of tangible long-lived assets and the associated asset retirement costs under SFAS 143 are reflected in the accompanying balance sheets.

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RECENT ACCOUNTING PRONOUNCEMENTS

On May 28, 2009 the Financial Accounting Standards Board (FASB) announced the issuance of FASB Statement No. 165, Subsequent Events (SFAS 165). The Statement should not result in significant changes in the subsequent events that an entity reports, rather specifies certain disclosure requirements related to the period of time in which an entity evaluates subsequent events. As such, SFAS 165 introduces the concept of financial statements being available to be issued. Financial statements are considered available to be issued when they are complete in a form and format that complies with generally accepted accounting principles (GAAP) and all approvals necessary for issuance have been obtained. SFAS 165 is effective for interim or annual financial periods ending after June 15, 2009, with prospective application. We anticipate SFAS No. 165 will not have a material impact on our financial statements.

In June 2009, the FASB issued SFAS No. 166, Accounting for Transfers of Financial Assets, an amendment to SFAS No. 140 (SFAS 166). SFAS 166 eliminates the concept of a “qualifying special-purpose entity,” changes the requirements for derecognizing financial assets, and requires additional disclosures in order to enhance information reported to users of financial statements by providing greater transparency about transfers of financial assets, including securitization transactions, and an entity’s continuing involvement in and exposure to the risks related to transferred financial assets. SFAS 166 is effective for fiscal years beginning after November 15, 2009. The Company will adopt SFAS 166 in fiscal 2010 and is evaluating the impact it will have on the consolidated results of the Company. We anticipate SFAS No. 166 will not have a material impact on our financial statements.

In June 2009, the FASB issued SFAS No. 167, Amendments to FASB Interpretation No. 46(R) (SFAS 167). The amendments include: (1) the elimination of the exemption for qualifying special purpose entities, (2) a new approach for determining who should consolidate a variable-interest entity, and (3) changes to when it is necessary to reassess who should consolidate a variable-interest entity. SFAS 167 is effective for the first annual reporting period beginning after November 15, 2009 and for interim periods within that first annual reporting period. The Company will adopt SFAS 167 in fiscal 2010 and is evaluating the impact it will have on the consolidated results of the Company.

In June 2009, the FASB issued SFAS No. 168, The FASB Accounting Standards Codification and the Hierarchy of Generally Accepted Accounting Principles (SFAS 168). SFAS 168 replaces FASB Statement No. 162, The Hierarchy of Generally Accepted Accounting Principles, and establishes the FASB Accounting Standards Codification TM (the Codification) as the source of authoritative accounting principles recognized by the FASB to be applied by nongovernmental entities in the preparation of financial statements in conformity with generally accepted accounting principles (GAAP). SFAS 168 is effective for interim and annual periods ending after September 15, 2009. The Company will begin to use the new Codification when referring to GAAP in its annual report on Form 10-K for the fiscal year ending January 3, 2010. This will not have an impact on the consolidated results of the Company.

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NOTE 2 -- ESTIMATES AND RISKS

The oil and gas industry is subject, by its nature, to environmental hazards and cleanup costs for which we carry liability insurance. At this time, we know of no substantial costs from environmental accidents or events for which we may be currently liable. In addition, our oil and gas business makes us vulnerable to changes in wellhead prices of crude oil and natural gas. Such prices have been volatile in the past and can be expected to be volatile in the future. By definition, proved reserves are based on current oil and gas prices. Price declines reduce the estimated proved reserves and increase annual amortization expense (which is based on proved reserves).

In evaluating our business, readers of this report should carefully consider the following factors in addition to the other information presented in this report and in our other reports filed with the SEC that advise interested parties of the risks and factors that may affect our business. As noted elsewhere herein, the future conduct of our business and discussions of possible future activities is dependent upon a number of factors, and there can be no assurance that we will be able to conduct our operations as contemplated herein. These risks include, but are not limited to:

§ The development and production of oil and gas enterprises is fraught with high risk, including the risk of fluctuating prices for oil and natural gas. Our revenues from low gas prices may not be sufficient to meet our overhead and operating expenses. § The fact that we are reliant on a single gas purchaser under an agreement that requires us to maintain certain quality standards. § The possibility that our gas transmission facilities and equipment may experience mechanical difficulties and breakdowns substantially curtailing our gas deliverability. § Severe weather conditions are typical in our area of operations and may cause interruptions of our ability to produce and/or deliver gas to our purchaser. § Our limited financial resources may impede our ability to maintain gas deliveries at current levels and our ability to increase such levels. § The possibility that the described operations, reserves, or development, re-completion or production activities will not be completed, continued or realized on economic terms, if at all. § Not developing adequate reserves despite expending large sums of money. § Test results and reserve estimates may not be accurate. § The possibility that the estimates on which we are relying are inaccurate and that unknown or unexpected future events may occur that will tend to reduce our ability to operate successfully, if at all. § Although we currently do not have active operations in the mining segment, mining exploration and mining have inherent risks including the environment, low prices for commodities, competition from better financed companies and the risk of failure in either exploration or mining. There is no assurance we will be able to compete successfully in the exploration and mining business should that course of action be undertaken.

§ The possibility that our gas transmission facilities and equipment may experience mechanical difficulties and breakdowns substantially curtailing our gas deliverability.

§ Severe weather conditions are typical in our area of operations and may cause interruptions of our ability to produce and/or deliver gas to our purchaser.

§ Our limited financial resources may impede our ability to maintain gas deliveries at current levels and our ability to increase such levels.

§ The possibility that the described operations, reserves, or development, re-completion or production activities will not be completed, continued or realized on economic terms, if at all.

§ The development and production of oil and gas enterprises attendant with high risk, including the risk of fluctuating prices for oil and natural gas.

§ Not developing adequate reserves despite expending large sums of money.

§ Test results and reserve estimates may not be accurate.

§ The possibility that the estimates on which we are relying are inaccurate and that unknown or unexpected future events may occur that will tend to reduce our ability to operate successfully, if at all.

§ Although we currently do not have active operations in the mining segment, mining exploration and mining have inherent risks including the environment, low prices for commodities, competition from better financed companies and the risk of failure in either exploration or mining. There is no assurance we will be able to compete successfully in the exploration and mining business should that course of action be undertaken.

See our Annual Report on Form 10-K for the fiscal year ended September 30, 2008 for additional risk factors.

NOTE 3 -- SEGMENT INFORMATION

We operate in two industry segments within the United States: (1) oil and gas exploration and development, and (2) a gas transmission pipeline.

- 910 -

Identified assets by industry are those assets that are used in our operations in each industry. Corporate assets are principally cash, investment securities, furniture, and fixtures.

We have adopted SFAS No. 131, which requires the presentation of descriptive information about reportable segments which is consistent with that made available to us in order to assess performance.

Our oil and gas segment derives its revenues from the sale of oil and gas. Corporate income is primarily derived from interest income on our funds held in money market accounts and the sale of government backed bonds. Our pipeline segment derives revenue from the sale, transportation and compression of our gas in Leavenworth County, Kansas.

During the ~~six~~nine months ended ~~March~~June 3130, 2009 and 2008, we had no inter-segment revenues. The accounting policies applied by each segment are the same as those we use in general.

Net sales to one customer of our oil and gas segment totaled $64156,~~183~~193, or 100% of our revenues for the ~~six~~nine months ended ~~March~~June 3130, 2009 as compared to $98203,~~290~~231, or 8892% for ~~the~~nine ~~six~~ months ended ~~March~~ 31June 30, 2008.

There have been no differences from our last Annual Report on Form 10-K in the bases of measuring segment profit or loss. Oil and gas and pipeline segments were impaired, under the accounting rules of SFAS No. 144, $498,124 and $201,564 respectively for a total impairment expense of $699,688.

Segment information for the ~~six~~nine months ended ~~March~~June 3130, 2009 and 2008 is as follows:

		~~Oil and Gas~~	Oil and Gas			~~Pipeline~~	Pipeline			~~Corporate~~	Corporate			~~Consolidated~~	Consolidated
Revenues
~~2009~~	2009	$	~~64,183~~$	84,119		$	~~50,228~~$	72,074		$	~~12,317~~$	16,543		$	~~126,728~~$	172,736
~~2008~~	2008		~~111,165~~	221,511			~~34,721~~	58,993			~~14,019~~	21,549			~~159,905~~	302,053
Net Income (Loss)
~~2009~~	2009	$	~~(507,075~~$	)(526,204	)	$	~~(261,179~~$	)(288,096	)	$	~~(140,897~~$	)(203,478	)	$	~~(909,151~~$	)(1,017,778	)
~~2008~~	2008		~~65,372~~	141,892			~~(64,340~~	)(102,461	)		~~(103,261~~	)(171,093	)		~~(102,229~~	)(131,662	)
Depreciation, Depletion
and Valuation Charged
to Identifiable Assets
~~2009~~	2009	$	~~25,465~~$	38,742		$	~~15,146~~$	24,165		$	~~1,826~~$	2,731		$	~~42,437~~$	65,638
~~2008~~	2008		~~19,790~~	36,943			~~24,779~~	44,496			~~3,717~~	1,024			~~48,286~~	82,463
Capital Expenditures
~~2009~~	2009	$	~~69,422~~$	78,677		$	~~28,138~~$	32,656		$	~~534~~$	954		$	~~98,094~~$	112,287
~~2008~~	2008		-	23,547			~~78,297~~	180,843			-	-			~~78,297~~	204,390
Segment information as of June 30, 2009 compared to September 30, 2008 is as follows.
Identifiable Assets
	June 30, 2009		$	516,498			$	199,672			$	521,762			$	1,237,932
	September 30, 2008			929,147				435,162				885,539				2,249,848

~~Segment~~- ~~information~~11 ~~as of March 31, 2009 compared to September 30, 2008 is as follows.~~-

Identifiable Assets
March 31, 2009	$	514,428	$	209,355	$	616,748	$	1,340,531
September 30, 2008		929,147		435,162		885,539		2,249,848

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NOTE 4 -- OIL AND GAS ACTIVITIES

KANSAS GAS PROJECT -- LEAVENWORTH COUNTY, KANSAS

During the quarter ended ~~March~~June 3130, 2009, we ~~completed~~started the ~~workover~~conversion of ~~one~~an existing gas well ~~which~~into ~~was~~a ~~recompleted~~water disposal inwell. This arequired ~~new~~us ~~productive~~to drill approximately 350 feet deeper into the disposal zone. This ~~recompletion~~conversion ~~enabled~~should enable us to ~~maintain~~dispose of ~~our~~additional ~~production~~water ~~level~~in atthe ~~from~~area ~~200-230~~and ~~MCF~~thus ~~per~~allow ~~day~~us to recomplete additional gas wells in a new productive zone. The Indisposal ~~addition~~well wewas completed ain ~~number~~early ofJuly, ~~equipment~~2009 ~~repairs~~and ~~which~~we ~~were~~plan ~~necessary~~ to ~~maintain~~recomplete ~~our~~from 2 – 4 gas ~~field~~wells ~~and~~in the disposal ~~pipeline~~well ~~operations~~area as soon as practical.

NOTE 5 – SHAREHOLDERS’ EQUITY

Under a Unit Purchase Agreement dated March 5, 2008, we sold 2,400,000 Units, each Unit consisting of one share of common stock and one common stock purchase warrant, at $0.25 per Unit, for a total of $600,000 in proceeds, including 400,000 Units to one of our officers (see Item 2. “Liquidity and Capital Resources page 12). Each warrant entitles the holder to purchase one share of common stock at an exercise price of $0.40 per share through March 4, 2010. The shares of common stock and the shares underlying the warrants contain certain registration rights.

As of January 1, 2009 we acquired a 2.5% overriding royalty interest in some of our Kansas gas properties from our consulting engineer who earned the interests under our 2001 agreement with him. In consideration for the interests, we paid $5,000 cash and issued 150,000 shares of our restricted common stock. No underwriters or sales agents were involved. The shares bear a restrictive legend against resale and the restriction is so noted in our transfer records. We relied on Section 4(2) under the Securities Act of 1933 as providing an exemption from the registration requirements of that Act since the issuance was made in an isolated transaction not involving a public offering.

NOTE 6 -- COMPREHENSIVE INCOME (LOSS)

Comprehensive income is the total of net income and all other non-owner changes in equity. Comprehensive income includes our net income and the change in unrealized gain (loss) on available for sale investments. We report the unrealized gain on the investment in securities in our Condensed Consolidated Balance Sheets. The table below details the changes during the six months ended ~~March~~June 3130, 2009 and 2008, in our Accumulated Other Comprehensive Income balance and the components of our comprehensive income.

~~Six~~Nine months ended ~~March~~June 3130, 2009

Accumulated other comprehensive loss at September 30, 2008	$	(7,~~989~~988	)
Change in unrealized loss on securities held for sale		32,~~522~~707
Accumulated other comprehensive income at March 31, 2009	$	(4,467	)
Accumulated other comprehensive income at June 30, 2009	$	(5,281	)

~~Six~~Nine months ended ~~March~~June 3130, 2008

Accumulated other comprehensive loss at September 30, 2007	$	(6,109	)
Change in unrealized loss on securities held for sale		91,~~635~~782
Accumulated other comprehensive loss at March 31, 2008	$	3,526
Accumulated other comprehensive loss at June 30, 2008	$	(4,327	)

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NOTE 7 – SUBSEQUENT EVENTS

On August 12, 2009 we held a Special Meeting of Shareholders and obtained approval from our shareholders to attempt to sell our Kansas properties and pipeline. See Part II, Item 4 hereof for further information.

We have evaluated subsequent events through August 12, 2009, the date which the financial statements were issued.

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

LIQUIDITY AND CAPITAL RESOURCES

At ~~March~~June 3130, 2009, our current assets were $~~623~~528,~~427~~262 and current liabilities were $~~128~~133,~~841~~203 and we had working capital of $~~494~~395,~~586~~059 compared to current assets of $921,862 and current liabilities of $167,488 and working capital of $754,374 at September 30, 2008. Our working capital decreased $~~259~~359,~~788~~315, or about 3448%. This decrease in working capital is due to the capital invested in property and equipment of approximately $98112,000 and our net operating loss of approximately $~~175~~248,000. This ~~for the~~amount ~~six~~does ~~months~~not ~~ended~~take ~~March~~into ~~31,~~consideration ~~2009.~~the ~~The~~ non-cash items of depletion and depreciation of $4265,~~437~~638 and impairment expense of $699,688~~, were also charged to our earnings for the same period~~.

Effective March 5, 2008, we sold 2,000,000 unregistered common shares of stock to an unaffiliated party and 400,000 shares of common stock to our president. The price was $0.25 per share, which included warrants to buy an additional unregistered common share of stock for each share purchased. The warrant exercise price is $0.40 per share and exercisable over two years. The total funds we received for the sale was $600,000. We are using these funds to re-complete some of our existing gas wells in Leavenworth County, Kansas and acquire additional gas wells and oil and gas leases in the Leavenworth County area if the opportunity arises. Refer to our report on Form 8-K which was filed with the Securities and Exchange Commission on March 6, 2008.

At the present time, our primary source of cash for operations and exploration is our current working capital, cash that can be raised by selling our investment in U.S. government sovereign agency securities and other corporate bonds and funds derived from our oil and gas operations. We expect that we will be spending our current working capital to support operations for the remainder of this fiscal year as natural gas prices are forecasted to remain relatively low. We have in the past, and plan in the future, to rely on joint venture partners or equity funding to supply some of the funds needed to evaluate and develop our properties. Any inability we may have to raise additional capital through a stock offering, to liquidate our securities holdings or obtain third party funding may limit development of most of our properties.

~~RESULTS~~On August 12, 2009, we obtained OFapproval ~~OPERATIONS~~from our shareholders to attempt to sell our Kansas properties and pipeline. See Part II, Item 4 hereof for further information.

Three Months Ended March 31, 2009 vs. 2008

Gas production increased from 16,606 MCF for the three month period ending March 31, 2008 to 17,720 MCF for the three month period ending March 31, 2009. This increase of 1,114 MCF was a result of our workover program increasing our production. The price received for our natural gas decreased from an average of $6.93 per MCF for the three months March 31, 2008 to an average of $3.28 per MCF for the three months ended March 31, 2009, a 53% decrease. Oil and gas sales decreased 62%, or $47,698, from $76,433 to $28,735 for the three months ended March 31, 2008 and 2009, respectively. This decrease is due to the substantial decrease in the price we received for our natural gas. Pipeline sales were $24,262 for the three months ended March 31, 2009 and $24,555 for the three months ended March 31, 2008, a decrease of $293, or 1%.

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Interest and other revenue decreased to $4,756 for the three months ended March 31, 2009 from $5,309 for the three months ended March 31, 2008. This decrease of $553 was due to the decrease in the interest rates we are currently able to receive on our bond investments. Oil and gas operating costs increased $12,306, or 92% from $13,346 to $25,652 when comparing the three months ended March 31, 2008 to March 31, 2009. This increase was primarily due to additional repairs and maintenance and supplies related to well workovers in progress. Pipeline operating costs were $53,213 for the three months ended March 31, 2009 and $37,947 for the three months ended March 31, 2008, an increase of $15,266, or 40% due to the addition of new field personnel and increased repairs and supplies related to increased compressor maintenance expenses.

General and administrative expenses totaled $74,235 for the three months ended March 31, 2009, compared to $53,055 for the three-month period ended March 31, 2008. This increase of $21,180, or 40%, in general and administrative costs was primarily due to the addition of a Vice President of Operations whose salary and taxes were approximately $7,000, other consulting costs of $2,000, accounting and audit of approximately $7,000 and field travel expenses of $5,000.

A net loss of $805,380 was recorded for the three months ended March 31, 2009 as compared to a net loss of $22,829 for the same period ended March 31, 2008. This increased loss of $782,551 was largely the result of recording approximately $700,000 in asset impairment expense, lower gas prices and increased maintenance and recompletion expenses.

Six Months Ended March 31, 2009 vs. 2008

Gas production increased from 23,252 MCF for the six month period ending March 31, 2008 to 36,070 MCF for six month period ending March 31, 2009. This increase of 12,818 MCF was a result of having full production in 2009 whereas during first quarter 2008 we relocated our compressor causing a production stoppage. The price received for our natural gas decreased from an average of $6.60 per MCF for the six months ended March 31, 2008 to an average of $3.47 per MCF for the six months ended March 31, 2009, a 47% decrease. Oil and gas sales decreased 42%, or $46,982, from $111,165 to $64,183 for six months ended March 31, 2008 and 2009, respectively. This decrease is due to the significantly lower average price received for our natural gas sales. Pipeline sales were $50,228 for the six months ended March 31, 2009 and $34,721 for the six months ended March 31, 2008, an increase of $15,507, or 45%. This increase was due to the increased production for the six months ended March 31, 2009 as described above.

Interest and other revenue decreased to $12,317 for the six months ended March 31, 2009 from $14,019 for the six months ended March 31, 2008. This decrease of $1,702 was due to the decrease in the interest rates we are currently receiving on our bond investments. Oil and gas operating costs increased $21,666, or 83% from $26,003 to $47,669 when comparing the six months ended March 31, 2008 to March 31, 2009. This increase was primarily due to increased production and increased maintenance and field personnel expenses. Pipeline operating costs were $94,697 for the six months ended March 31, 2009 and $74,282 for the six months ended March 31, 2008, an increase of $20,415, or 27% as a result of increased operations, the addition of new field personnel and increased repairs and supplies.

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~~General and administrative expenses~~RESULTS ~~totaled~~OF $151,388 for the six months ended March 31, 2009, compared to $113,563 for the six month period ended March 31, 2008. This increase of $37,825, or 33%, in general and administrative costs was primarily due to increased accounting fees of approximately $8,000, the addition of Vice President of Operations’ salary and related employment taxes of approximately $14,000 and increased consulting costs of $2,000 in the six month period ended March 31, 2009 and an insurance refund received in the same period of 2008 which reduced insurance costs for the same period of 2008 by $15,000.OPERATIONS

~~A net loss of $909,151 was recorded for~~Three ~~the~~Months ~~six~~Ended ~~months~~June ~~ended March 31~~30, 2009 ~~as compared to a net loss of $102,229 for the same period ended March 31, 2008~~vs. ~~This~~ increased loss of $806,922 was primarily the result of recording approximately $700,000 in asset impairment expense, decreased natural gas prices and greater expenses during the six months ended March 31, 2009 as described above.2008

Gas production increased from 15,629 MCF for the three month period ending June 30, 2008 to 18,163 MCF for the three month period ending June 30, 2009. This increase of 2,534 MCF was a result of our workover program. The price received for our natural gas decreased from an average of $8.85 per MCF for the three months June 30, 2008 to an average of $2.48 per MCF for the three months ended June 30, 2009, a 72% decrease. Oil and gas sales decreased 82%, or $90,410, from $110,346 to $19,936 for the three months ended June 30, 2008 and 2009, respectively. This decrease is due to the substantial decrease in the price we received for our natural gas. Pipeline sales were $21,846 for the three months ended June 30, 2009 and $24,272 for the three months ended June 30, 2008, a decrease of $2,426, or 10%.

Interest and other revenue decreased to $4,226 for the three months ended June 30, 2009 from $7,530 for the three months ended June 30, 2008. This decrease of $3,304 was due to the decrease in the interest rates we are currently able to receive and the decrease in cash invested in our bond investments. Oil and gas operating costs increased $9,115, or 55% from $16,673 to $25,788 when comparing the three months ended June 30, 2008 to June 30, 2009. This increase was primarily due to additional repairs and maintenance and supplies related to well workovers in progress. Pipeline operating costs were $39,744 for the three months ended June 30, 2009 and $42,676 for the three months ended June 30, 2008, a decrease of $2,932, or 7% due to a decrease in supply expense incurred in the three months ended June 30, 2009 from purchasing in large quantities.

General and administrative expenses totaled $65,902 for the three months ended June 30, 2009, compared to $78,055 for the three-month period ended June 30, 2008. This decrease of $12,153, or 16%, in general and administrative costs was primarily due to a decrease in legal and corporate report expenses associated with the private placement offering incurred in the three months ended June 30, 2008.

A net loss of $108,627 was recorded for the three months ended June 30, 2009 as compared to a net loss of $29,433 for the same period ended June 30, 2008. This increased loss of $79,194 was largely the result of lower gas prices.

Nine Months Ended June 30, 2009 vs. 2008

Gas production increased from 38,882 MCF for the nine month period ending June 30, 2008 to 54,233 MCF for nine month period ending June 30, 2009. This increase of 15,351 MCF was a result of having full production in 2009 whereas during first quarter 2008 we relocated our compressor causing a production stoppage. The price received for our natural gas decreased from an average of $7.49 per MCF for the nine months ended June 30, 2008 to an average of $3.14 per MCF for the nine months ended June 30, 2009, a 58% decrease. Oil and gas sales decreased 62%, or $137,392, from $221,511 to $84,119 for nine months ended June 30, 2008 and 2009, respectively. This decrease is due to the significantly lower average price received for our natural gas sales. Pipeline sales were $72,074 for the nine months ended June 30, 2009 and $58,993 for the nine months ended June 30, 2008, an increase of $13,081, or 22%. This increase was due to the increased production for the nine months ended June 30, 2009 as described above.

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Interest and other revenue decreased to $16,480 for the nine months ended June 30, 2009 from $21,549 for the nine months ended June 30, 2008. This decrease of $5,069 was due to the decrease in the interest rates we are currently receiving and the decrease in cash invested in our bond investments. Oil and gas operating costs increased $30,781, or 72% from $42,676 to $73,457 when comparing the nine months ended June 30, 2008 to June 30, 2009. This increase was primarily due to increased production and increased maintenance and field personnel expenses. Pipeline operating costs were $134,441 for the nine months ended June 30, 2009 and $116,958 for the nine months ended June 30, 2008, an increase of $17,483, or 15% as a result of increased operations, the addition of new field personnel and increased repairs and supplies.

General and administrative expenses totaled $217,290 for the nine months ended June 30, 2009, compared to $191,618 for the nine month period ended June 30, 2008. This increase of $25,672, or 13%, in general and administrative costs was primarily due to increased accounting fees of approximately $4,000, the addition of Vice President of Operations’ salary and related employment taxes of approximately $14,000 and increased consulting costs of $6,000 in the nine month period ended June 30, 2009.

A net loss of $1,017,778 was recorded for the nine months ended June 30, 2009 as compared to a net loss of $131,662 for the same period ended June 30, 2008. This increased loss of $886,116 was primarily the result of recording approximately $700,000 in asset impairment expense, decreased natural gas prices and greater expenses during the nine months ended June 30, 2009 as described above.

CONTRACTUAL OBLIGATIONS

We have no contractual obligations as of ~~March~~June 3130, 2009.

We lease our corporate offices in Denver, Colorado on a month-to-month basis. Yearly payments under the lease are $12,456.

CRITICAL ACCOUNTING POLICIES AND ESTIMATES

We believe the following critical accounting policies affect our more significant judgments and estimates used in the preparation of our Condensed Consolidated Financial Statements.

Reserve Estimates:

Our estimates of oil and natural gas reserves, by necessity, are projections based on geological and engineering data, and there are uncertainties inherent in the interpretation of such data as well as the projection of future rates of production and the timing of development expenditures. Reserve engineering is a subjective process of estimating underground accumulations of oil and natural 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. Estimates 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 and excise taxes, development costs and workover and remedial costs, all of which may in fact vary considerably from actual results. For these reasons, estimates of the economically recoverable quantities of oil and natural gas attributable to any particular group of properties, classifications of such reserves based on risk of recovery, and estimates of the future net cash flows expected there from 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 our oil and gas properties and/or the rate of depletion of the oil and gas properties. Actual production, revenues and expenditures with respect our reserves will likely vary from estimates, and such variances may be material.

~~cash~~- ~~flows~~15 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 and excise taxes, development costs and workover and remedial costs, all of which may in fact vary considerably from actual results. For these reasons, estimates of the economically recoverable quantities of oil and natural gas attributable to any particular group of properties, classifications of such reserves based on risk of recovery, and estimates of the future net cash flows expected there from 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 our oil and gas properties and/or the rate of depletion of the oil and gas properties. Actual production, revenues and expenditures with respect our reserves will likely vary from estimates, and such variances may be material.-

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Many factors will affect actual net cash flows, including:

· the amount and timing of actual production;

· supply and demand for natural gas;

· curtailments or increases in consumption by natural gas purchasers; and

· changes in governmental regulations or taxation.

Oil and Gas Properties:

We follow the successful efforts method of accounting for acquisition, exploration, development and production of its oil and gas properties. Under this method, all direct costs of acquisition, exploration and development are capitalized with respect to producing wells and non-producing development wells. Direct costs with respect to non-producing exploratory wells are charged to operations. Geological and geophysical costs and lease rentals are expensed as incurred. Costs to acquire interests in leases are capitalized and are either transferred to producing properties when the properties become productive or expensed when the interests are surrendered. Developed and proved properties are periodically assessed under the accounting rules of Statement of Financial Accounting Standards (“SFAS”) No. 144, “Accounting for the Impairment or Disposal of Long-Lived Asset”. Under SFAS No. 144, the Company evaluates quarterly the carrying value of long-lived assets and long-lived assets to be disposed of and certain identifiable intangibles related to those assets for potential impairment. This impairment is a non-cash charge to earnings. If required, it reduces earnings and impacts shareholders’ equity in the period of occurrence and results in lower depreciation and depletion in future periods. The impairment may not be reversed in future periods, even though higher oil and gas prices may subsequently increase the recoverability of costs invested. As of ~~March~~June 3130, 2009 natural gas prices were significantly lower than at previous measurement dates indicating that the carrying value of our assets might not be recoverable from expected future cash flows and therefore under SFAS No. 144 should be adjusted to fair market value as determined by discounting the expected cash flows by an interest rate commensurate with the risks involved with those cash flows which we determined to be 10%. Accordingly, we recorded an impairment of oil and gas and pipeline properties of $699,688 ~~for~~which ~~the~~is ~~three~~reflected ~~month~~in ~~and~~the ~~six~~nine month period ending ~~March~~June 3130, 2009 as compared to no impairment expense during the same ~~periods~~period ended ~~March~~June 3130, 2008.

Unproved oil and gas properties represent undeveloped lease acreage held for development and are recorded at cost. An impairment allowance for unproved properties is determined on a property-by-property basis under the accounting rules of SFAS No. 19, “Financial Accounting and Reporting by Oil and Gas Producing Companies”.

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Item 3. QUANTITATIVE AND QUALITATIVE DISCLOSURE ABOUT MARKET RISK

As a crude oil and natural gas producer, our revenue, cash flow from operations, other income and profitability, reserve values, access to capital and future rate of growth are substantially dependent upon the prevailing prices of crude oil and natural gas. Declines in commodity prices will materially adversely effect our financial condition, liquidity, ability to obtain financing and operation results. Lower commodity prices may reduce the amount of crude oil and natural gas that we can produce economically. Prevailing prices for such commodities are subject to wide fluctuation in response to relatively minor changes in supply and demand and a variety of additional factors beyond our control, such as global, political and economic conditions. Historically, prices received for crude oil and natural gas production have been volatile and unpredictable, and such volatility is expected to continue. Most of our production is sold at market prices. Generally, if the commodity indexes fall, the price that we receive for our production will also decline. Therefore, the amount of revenue that we realize is partially determined by factors beyond our control.

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and demand and a variety of additional factors beyond our control, such as global, political and economic conditions. Historically, prices received for crude oil and natural gas production have been volatile and unpredictable, and such volatility is expected to continue. Most of our production is sold at market prices. Generally, if the commodity indexes fall, the price that we receive for our production will also decline. Therefore, the amount of revenue that we realize is partially determined by factors beyond our control.

Item 4. CONTROLS AND PROCEDURES

As of the end of the period covered by this report, we conducted an evaluation, under the supervision and with the participation of our principal executive and financial officer, of our disclosure controls and procedures (as defined in Rules 13a-15(e) and 15d-15(e)) under the Securities Exchange Act of 1934 (the “Exchange Act”). Based on this evaluation, the principal executive and financial officer concluded that our disclosure controls and procedures are effective to ensure that information required to be disclosed by us in reports that we file or submit under the Exchange Act is recorded, processed, summarized and reported within the time periods specified in Securities and Exchange Commission rules and forms. There was no change in our internal control over financial reporting during our most recently completed fiscal quarter that has materially affected or is reasonably likely to materially affect our internal control over financial reporting.

In connection with the audit of the year ended September 30, 2008, there were no “Reportable Events” within the meaning of Item 304(a)(1)(v) of Regulation S-K.

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MONUMENT RESOURCES, INC. AND SUBSIDIARY

PART II -- OTHER INFORMATION

ITEM 1. LEGAL PROCEEDINGS.

ITEM 1.	LEGAL PROCEEDINGS.

	None

ITEM 1A.	RISK FACTORS.

	See our Annual Report on Form 10-K for the fiscal year ended September 30, 2008 and the various risks described in Part I hereof.

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

	None

ITEM 3.	DEFAULTS UPON SENIOR SECURITIES.

	None

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

	On August 12, 2009, we held a special shareholders meeting to (i) obtain approval to sell substantially all of our assets, and (ii) obtain approval to conditionally dissolve the company. If we are able to sell our assets, make a cash distribution to shareholders, we will attempt to enter into a transaction using our company as a public shell corporation for another business venture. Our reasons for this meeting and its implications are set forth in our proxy statement dated July 14, 2009 incorporated herein by reference.

	The results of voting at the special meeting were as follows:

None

Proposal	For	Against	Abstain
Sale of Assets	6,125,945	24,500	- 0 -
Conditional Dissolution	6,125,945	24,500	- 0 -

ITEM 1A. RISK FACTORS.

ITEM 5.	OTHER INFORMATION.

	None

ITEM 6.	EXHIBITS

		Exhibit 31.1--Certification of the Chief Executive and Financial Officer under Section 302 of the Sarbanes-Oxley Act of 2002.

		Exhibit 32.1--Certification of the Chief Executive and Financial Officer under Section 906 of the Sarbanes-Oxley Act of 2002.

~~See our Annual Report on Form 10~~-~~K for the fiscal year ended September 30, 2008 and the~~ ~~various~~18 ~~risks described in Part I hereof.~~-

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

ITEM 3. DEFAULTS UPON SENIOR SECURITIES.

None

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

None

ITEM 5. OTHER INFORMATION.

None

ITEM 6. EXHIBITS

Exhibit 31.1--Certification of the Chief Executive and Financial Officer under Section 302 of the Sarbanes-Oxley Act of 2002.

Exhibit 32.1--Certification of the Chief Executive and Financial Officer under Section 906 of the Sarbanes-Oxley Act of 2002.

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SIGNATURES

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

	MONUMENT RESOURCES, INC. (Registrant)
Date: May 12, 2009	By:	/s/ A.G. Foust
Date: August 12, 2009	By:	/s/ A.G. Foust
		A.G. Foust, President (Chief Executive Officer, Principal Financial and Accounting Officer)

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EXHIBIT INDEX

EXHIBIT
NUMBER	DESCRIPTION
31.1	Certification of Chief Executive and Financial Officer under Section 302 of the Sarbanes-Oxley Act of 2002.
32.1	Certification of Chief Executive and Financial Officer under Section 906 of the Sarbanes-Oxley Act of 2002.

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EXHIBIT INDEX

EXHIBIT
NUMBER	DESCRIPTION

31.1	Certification of Chief Executive and Financial Officer under Section 302 of the Sarbanes-Oxley Act of 2002.

32.1	Certification of Chief Executive and Financial Officer under Section 906 of the Sarbanes-Oxley Act of 2002

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Filing Compare · MONUMENT RESOURCES INC