Tri Valley (TIV) 10-K/A 2004 FY Annual report (amended)

              As filed with the Securities and Exchange Commission on September 20, 2005

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

FORM 10-K/A

AMENDMENT NO. 3 TO

ANNUAL REPORT PURSUANT TO SECTION 13 OR 15(d)

OF THE SECURITIES EXCHANGE ACT OF 1934

For the Fiscal Year Ended December 31, 2004 Commission File No. 001-31852

TRI-VALLEY CORPORATION

(Exact Name of Registrant as Specified in its Charter)

Delaware	84-0617433
(State or other jurisdiction of incorporation or organization)	(I.R.S. Employer Identification No.)

5555 Business Park South, Suite 200, Bakersfield, California 93309

(Address of Principal Executive Offices)

Registrant's Telephone Number Including Area Code:(661) 864-0500

Securities Registered Pursuant to Section 12(b) of the Act:

None

Securities Registered Pursuant to Section 12(g) of the Act:

Common Stock, $0.001 par value

(Title of Class)

Indicate by check mark whether the registrant (1) has filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrant was required to file such reports), and (2) has been subject to such requirement for the past 90 days.Yes [x] No [  ]

Indicate by check mark if disclosure of delinquent filers pursuant to Item 405 of Regulation S-K (Section 229.405 of this chapter) is not contained herein, and will not be contained to the best of the registrant's knowledge, in definitive proxy or information statements incorporated by reference in Part III of this Form 10-K or any amendment to this Form 10-K.         [x]

Indicate by check mark whether the registrant is an accelerated filer (as defined in Rule 12b-2 of the Act). Yes [x] No [  ]

As of June 30, 2005, 22,460,302 common shares were issued and outstanding.

The aggregate market value of the common shares of Tri-Valley Corporation held by non-affiliates on June 30, 2005, was approximately $295,930,424.

DOCUMENTS INCORPORATED BY REFERENCE: None

TABLE OF CONTENTS

PART I
ITEM 1	Business	1
	Competition	1
	Governmental Regulation	1
	Environmental Regulation	2
	Employees	3
	Available Information	3
ITEM 2	Properties	3
	Oil and Gas Operations	4
	Mining Activity	6
ITEM 4	Submission of Matters To A Vote Of Security Holders	6
PART II
ITEM 5	Market Price Of The Registrant's Common Stock And Related Security Holder Matters	7
	Recent Sales of Unregistered Securities	7
ITEM 6	Selected Historical Financial Data	8
ITEM 7	Management's Discussion And Analysis Of Financial Condition	8
	Notice Regarding Forward-Looking Statements	8
	Overview	8
	Restatements	9
	Critical Accounting Policies	9
	Results of Operations	12
	Financial Condition	14
ITEM 8	Financial Statements	17
ITEM 9A	Controls and Procedures	50
	Evaluation of Disclosure Controls	50
	Management Report on Internal Control	50
	Report of Independent Registered Public Accounting Firm	51
PART III
ITEM 10	Directors and Executive Officers of the Registrant	53
ITEM 11	Executive Compensation	56
	Employment Agreement with Our President	56
	Compensation Committee Report	56
	Aggregated 2003 Option Exercises and Year-End Values	57
	Compensation of Directors	57
	Performance Graph	58
ITEM 12	Security Ownership of Certain Beneficial Owners and Management	58
ITEM 14	Principal Accountant Fees and Services	59
ITEM 15	Exhibits and Financial Statement Schedules	59
SIGNATURES		60

PART I

ITEM 1 Business

Tri-Valley Corporation, a Delaware corporation formed in 1971, is in the business of exploring, acquiring and developing prospective and producing petroleum, industrial minerals and precious metals properties and interests therein. Substantially all of our oil and gas reserves are located in northern California. In 2004, Tri-Valley had three wholly owned subsidiaries: Tri-Valley Oil & Gas Company, Select Resources Corporation Inc., and Tri-Valley Power Corporation.

Tri-Valley Oil & Gas Company ("TVOG") operates the oil & gas activities. TVOG derives the majority of its revenue from oil and gas drilling and development. TVOG primarily generates its own exploration prospects from its internal database, and also screens prospects from other geologists and companies. TVOG generates these geological "plays" within a certain geographic area of mutual interest. The prospect is then presented to potential co-ventures. The company deals with both accredited individual investors and energy industry companies. TVOG is the operator of these co-ventures.

We sell substantially all of our oil and gas production to ConocoPhillips. Other gatherers of oil and gas production operate within our area of operations in California, and we are confident that if ConocoPhillips ceased purchasing our production we could find another purchaser on similar terms with no adverse consequences to our income or operations.

In 1987, we acquired precious metals claims on Alaska state lands. We have conducted exploration operations on these properties and have reduced our original claims to a block of approximately 28,720 acres (44.9 square miles). We have conducted trenching, core drilling, bulk sampling and assaying activities to date and have reason to believe that mineralization exists to justify additional exploration activities. However, to date, we have not identified probable mineral reserves on these properties. There is no assurance that a commercially viable mineral deposit exists on any of these above-mentioned mineral properties. Further exploration is required before a final evaluation as to the economic and legal feasibility can be determined.

In December 2004, we created Select Resources Corporation as a wholly owned subsidiary. In 2004, Select Resources engaged in limited activities associated with its organization. We expect to transfer our existing gold mining properties located near Richardson, Alaska, to this new subsidiary. In addition, the new subsidiary will endeavor to acquire and develop new precious metals and other industrial mineral properties.

Tri-Valley Power Corporation is the third wholly owned subsidiary. However, this subsidiary is inactive at the present time.

Competition

The oil and gas industry is highly competitive in all its phases. Competition is particularly intense with respect to the acquisition of desirable producing properties, the acquisition of oil and gas prospects suitable for enhanced production efforts, and the hiring of experienced personnel. Our competitors in oil and gas acquisition, development, and production include the major oil companies in addition to numerous independent oil and gas companies, individual proprietors and drilling programs. Many of these competitors possess and employ financial and personnel resources substantially greater than those which are available to us and may be able to pay more for desirable producing properties and prospects and to define, evaluate, bid for, and purchase a greater number of producing properties and prospects than we can. Our financial or personnel resources to generate reserves in the future will be dependent on our ability to select and acquire suitable producing propert ies and prospects in competition with these companies.

Governmental Regulation

Domestic exploration for the production and sale of oil and gas is extensively regulated at both the federal and state levels. Legislation affecting the oil and gas industry is under constant review for amendment or expansion,

frequently increasing the regulatory burden. Also, numerous departments and agencies, both federal and state, are

1

authorized by statute to issue, and have issued, rules and regulations affecting the oil and gas industry which often are difficult and costly to comply with and which carry substantial penalties for noncompliance. State statutes and regulations require permits for drilling operations, drilling bonds, and reports concerning operations. Most states in which we will operate also have statutes and regulations governing conservation matters, including the unitization or pooling of properties and the establishment of maximum rates of production from wells. Many state statutes and regulations may limit the rate at which oil and gas could otherwise be produced from acquired properties. Somestates have also enacted statutes prescribing ceiling prices for natural gas sold within their states. Our operations are also subject to numerous laws and regulations governing plugging and abandonment, the discharge of materials into the environment or otherwise relating to environmental p rotection. The heavy regulatory burden on the oil and gas industry increases its costs of doing business and consequently affects its profitability. We cannot be sure that a change in such laws, rules, regulations, or interpretations, will not harm our financial condition or operating results.

Environmental Regulation

Mining Activities

Mining activities in the United States are subject to federal and state laws and regulations covering mining safety and environmental quality. However, because we do not have active mining operations at present, these regulations have little impact on our current activities. In 2004, 2003 and 2002, the regulatory requirements had no significant effect on our precious metals activity as we continued our exploration efforts.

Should we seek to develop our precious metals claims, development efforts would require compliance with mining laws and regulations. State and federal laws impose minimum safety standards to protect workers in the construction and development of mines and conduct of mining operations. Mining activities are subject to environmental regulation of the output of mines, particularly in the storage and disposal of waste from mining operations. Environmental regulations restrict the storage, use and disposal of both the materials used in mining operations and the waste contained in mineral ore, all of which contain toxic materials that would damage the surrounding land and ground water if not carefully handled.

In addition, federal and state regulations call for reclamation of land which has been altered by mining activities. These regulations may require significant expenditures to clean up a mining site during and after mining.

Before we could begin actual mining operations on our claims, we would have to develop a feasibility study which would, among other things, address the potential costs of labor, safety and environmental regulation on any proposed mining activity.

Energy Operations

Our energy operations are subject to risks of fire, explosions, blow-outs, pipe failure, abnormally pressured formations and environmental hazards, such as oil spills, natural gas leaks, ruptures or discharges of toxic gases, the occurrence of any of which could result in substantial losses due to injury or loss of life, severe damage to or destruction of property, natural resources and equipment, pollution or other environmental damage, clean-up responsibilities, regulatory investigation and penalties and suspension of operations. In accordance with customary industry practice, we maintain insurance against these kinds of risks, but we cannot be sure that our level of insurance will cover all losses in the event of a drilling or production catastrophe. Insurance is not available for all operational risks, such as risks that we will drill a dry hole, fail in an attempt to complete a well or have problems maintaining production from existing wells.

Oil and gas activities can result in liability under federal, state, and local environmental regulations for activities involving, among other things, water pollution and hazardous waste transport, storage, and disposal. Such liability can attach not only to the operator of record of the well, but also to other parties that may be deemed to be current or prior operators or owners of the wells or the equipment involved. Numerous governmental agencies issue rules and regulations to implement and enforce such laws, which are often difficult and costly to comply with and which carry substantial administrative, civil and criminal penalties and in some cases injunctive relief for failure to comply. Some laws, rules and regulations relating to the protection of the environment may, in certain circumstances, impose "strict liability" for environmental contamination. These laws render a person or company liable for environmental

2

and natural resource damages, cleanup costs and, in the case of oil spills in certain states, consequential damages without regard to negligence or fault. Other laws, rules and regulations may require the rate of oil and gas production to be below the economically optimal rate or may even prohibit exploration or production activities in environmentally sensitive areas. In addition, state laws often require some form of remedial action, such as closure of inactive pits and plugging of abandoned wells, to prevent pollution from former or suspended operations.

The federal Comprehensive Environmental Response, Compensation and Liability Act, or CERCLA, also known as the "Superfund" law, imposes liability, without regard to fault, on certain classes of persons with respect to the release of a "hazardous substance" into the environment. These persons include the current or prior owner or operator of the disposal site or sites where the release occurred and companies that transported, disposed or arranged for the transport or disposal of the hazardous substances found at the site. Persons who are or were responsible for releases 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, and it is not uncommon for the federal or state government to pursue such claims. It is also not uncommon for neighboring landowners and other third parties to file claims for personal inju ry or property or natural resource damages allegedly caused by the hazardous substances released into the environment. Under CERCLA, certain oil and gas materials and products are, by definition, excluded from the term "hazardous substances." At least two federal courts have held that certain wastes associated with the production of crude oil may be classified as hazardous substances under CERCLA. Similarly, under the federal Resource, Conservation and Recovery Act, or RCRA, which governs the generation, treatment, storage and disposal of "solid wastes" and "hazardous wastes," certain oil and gas materials and wastes are exempt from the definition of "hazardous wastes." This exemption continues to be subject to judicial interpretation and increasingly stringent state interpretation. During the normal course of operations on properties in which we have an interest, exempt and non-exempt wastes, including hazardous wastes, that are subject to RCRA and comparable state statutes and implementing regulations are generated or have been generated in the past. The federal Environmental Protection Agency and various state agencies continue to promulgate regulations that limit the disposal and permitting options for certain hazardous and non-hazardous wastes.

Compliance with environmental requirements, including financial assurance requirements and the costs associated with the cleanup of any spill, could have a material adverse effect on our capital expenditures or earnings. These laws and regulations have not had a material affect on our capital expenditures or earnings to date. Nevertheless, changes in environmental laws have the potential to adversely affect operations. At this time, we have no plans to make any material capital expenditures for environmental control facilities.

Employees

We had a total of five full-time employees, one part-time bookkeeper, and three consultants on December 31, 2004.

Available Information

We file annual and quarterly reports, proxy statements and other information with the Securities and Exchange Commission using SEC's EDGAR system. The SEC maintains a site on the Internet at http://www.sec.gov that contains reports, proxy and information statements and other information regarding us and other registrants that file reports electronically with the SEC. You may read and copy any materials that we file with the SEC at its Public Reference Room at 450 5th Street, N.W., Washington, D.C. 20549. Our common stock is listed on the American Stock Exchange, under the symbol TIV. Please call the SEC at 1-800-SEC-0330 for further information about their public reference rooms. Our website is located at http://www.tri-valleycorp.com.

We furnish our shareholders with a copy of our annual report on Form 10-K, which contains audited financial statements, and such other reports as we, from time to time, deem appropriate or as may be required by law. We use the calendar year as our fiscal year.

ITEM 2 Properties

Our headquarters and administrative offices are located at 5555 Business Park South, Suite 200, Bakersfield, California 93309. We lease approximately 4,500 square feet of office space at that location. Our principal properties

3

consist of proven and unproven oil and gas properties, mining claims on unproven precious metals properties, maps and geologic records related to prospective oil and gas and unproven precious metal properties, office and other equipment. TVOG has a worldwide geologic library with data on every continent except Antarctica including over 700 leads and prospects in California,our present area of emphasis.

Oil and Gas Operations

The oil and gas properties in whichwe hold interests are primarily located in the area of central California known as the Sacramento Valley.We alsolease exploration acreage in the San Joaquin and Santa Maria Valleys.Tri-Valley contracts for the drilling of all wells and do not own any drilling equipment, bulk storage facilities, or refineries. Tri-Valley do own a small segment of pipeline at Tracy, California.

Tri-Valley has retained the services of Cecil Engineering, an independent engineer qualified to estimateour net share of proved developed oil and gas reserves on allof our oil and gas properties at December 31, 2004 for SEC filing.We do not include any undeveloped reserves in these reserve studies. Only proved developed reserves arelisted in our reserve report. Price is a material factor inour stated reserves, because higher prices permit relatively higher-cost reserves to be produced economically. Higher prices generally permit longer recovery, hence larger reserves at higher values. Conversely, lower prices generally limit recovery to lower-cost reserves, hence smaller reserves. The process of estimating oil and gas reserve quantities is inherently imprecise. Ascribing monetary values to tho se reserves, therefore, yields imprecise estimated data at best.

Our estimated future net recoverable oil and gas reserves from proved developed properties as of December 31, 2004, December 31, 2003 and December 31, 2002 were as follows:

	BBL		MCF
December 31, 2004	Condensate	162	Natural Gas	742,401
December 31, 2003	Condensate	162	Natural Gas	1,251,548
December 31, 2002	Condensate	150	Natural Gas	1,492,245

Using year-end oil and gas prices and current levels of lease operating expenses, the estimated present value of the future net revenue to be derived fromour proved developed oil and gas reserves, discounted at 10%, was $1,958,238 at December 31, 2004, $2,270,632 at December 31, 2003, and $2,224,270 at December 31, 2002. At December 31, 2004, we had no significant proved undeveloped reserves. The unaudited supplemental information attached to the consolidated financial statements provides more information on oil and gas reserves and estimated values.

The following table sets forth the net quantities of natural gas and crude oilthat we produced during:

	Year Ended	Year Ended	Year Ended
	December 31,	December 31,	December 31,
	2004	2003	2002
Natural Gas (MCF)	126,942	162,314	232,578
Crude Oil (BBL)	22	25	29

The following table sets forth our average sales price and average production (lifting) cost per unit of oil and gas produced during:

4

	Year Ended December 31,
	2004		2003		2002
	Gas (Mcf)	Oil*	Gas (Mcf)	Oil*	Gas (Mcf)	Oil*
Sales Price	$5.66	$40.60	$5.07	$29.46	$3.07	$19.13
Production Costs	$1.14	0	$0.78	0	$0.98	0
Net Profit	$4.52	$40.60	$4.29	$29.46	$2.09	$19.13

* The only oil produced in each year was condensate (oil related to natural gas that must be separated to produce the gas). The cost of separation is included in our gas production costs, and we do not separately determine the cost of producing oil condensate. Condensate forms an insignificant amount of our production revenue and costs

As of December 31, 2004we had the following gross and net position in wells and developed acreage:

Wells (1)		Acres (2)
Gross	Net	Gross	Net
11	4.537	2,192	645

(1)	"Gross" wells represent the total number of producing wells in whichwe have a working interest. "Net" wells represent the number of gross producing wells multiplied by the percentages of the working interestswhich we own. "Net wells" recognizes only those wells in whichwe hold an earned working interest. Working interests earned at payout have not been included.
(2)	"Gross" acres represent the total acres in whichwe have a working interest; "net" acres represent the aggregate of the working interestswhich we own in the gross acres.

The following table sets forth the number of productive and dry exploratory and development wellswhich we drilledduring:

	Year Ended	Year Ended	Year Ended
	December 31,	December 31,	December 31,
	2004	2003*	2002
Exploratory
Producing	-0-	-0-	-0-
Recompleting			1
Dry	1	2	2
Total	1	2	3
Development
Producing	-0-	-0-	-0-
Dry	-0-	-0-	-0-
Total	-0-	-0-	-0-

* We drilled three wells in 2003, which were still being evaluated at December 31, 2003. In 2004 we determined to abandon two of those wells as dry holes. We have attempted to complete the third well drilled in 2003, and as of August 15, 2005, were still evaluating whether that well can be successfully completed as a commercial well and whether additional work is necessary.

The following table sets forth information regarding undeveloped oil and gas acreage in whichwe had an interest on December 31, 2004:

5

State	Gross Acres	Net Acres
California	34,879	29,971
Nevada	21,737	21,737

Some ofour undeveloped acreage is held pursuant to leases from landowners. Such leases have varying dates of execution and generally expire one to five years after the date of the lease. In the next three years, the following lease gross acreage expires:

Expires in 2005	7,151 acres
Expires in 2006	4,260 acres
Expires in 2007	160 acres

Mining Activity

The precious metals properties are located in interior Alaska. They are comprised of 626 40-acre claims and 15 160-acre claims, of which 104 claims are leased from others, all are located solely on State owned lands requiring annual assessment work, and an annual per claim fee. All fees are current. During 2004, the Company staked 12 new 40-acre claims and 5 new 160-acre claims for a total of 1,280 additional acres.

The mining claim block covers about 44.9 square miles or 28,720 acres of land, all of which is owned by the State of Alaska. The claims lie within T-5-6-7 S, R 5-6-7-8 E, Fairbanks Meridian, immediately north of the Richardson Highway, an all-weather paved highway that connects Fairbanks, Alaska, with points south and east. Fairbanks is approximately 65 miles northwest of Richardson, and Delta Junction, also on the highway, is about 30 miles to the southeast. The Trans Alaska Pipeline corridor is near the northeastern edge of the claim block and the service road along the pipeline provides access to the claims from the north. Numerous good to fair dirt roads traverse the claims.

The following table sets forth the information regarding the acreage position we have under lease in Alaska as of December 31, 2004:

State	Gross Acres	Net Acres
Alaska	28,720	27,926

Mineral properties claimed onopen state land require minimum annual assessment work of $100 worth per State of Alaska claim. Expenditures on the Richardson, Alaska acreage have already carried forward annual assessment requirements more than four years on all its claims. We have no Federal claims.

We have had a joint scientific research agreement with TsNIGRI, the Central Research Institute of Geological Prospecting for Base and Precious Metals, based in Moscow, Russia since 1991. The proprietary technology they use for evaluating large areas of covered sub-arctic terrain has been impressive and encouraging to our efforts. Minute amounts of gold have been found in samples at 60 locations along a 20-mile swathand over 1,000 samples have been assayed by Bondar-Clegg, a respected assay house.

We intend to continue our exploration efforts for precious metals on our claim block in Richardson, Alaska. With the help of TsNIGRI, we have explored and evaluated this property during the summer months, due to the constraints of the weather in the winter months. This work will consist of field activity which includes drilling core holes, mapping and other geological work.

ITEM 4 Submission of Matters To A Vote Of Security Holders

We held our annual meeting on October 25, 2004. At the meeting, the shareholders re-elected all of the six directors who were recommended by the board.

The shareholder votes were as follows:

6

Measure #1 - Election of Directors

	FOR	AGAINST	ABSTAIN
F. Lynn Blystone	19,344,013	37,630
Milton J. Carlson	19,344,088	37,555
C. Chase Hoffman	19,344,088	37,555
Dennis P. Lockhart	19,342,588	39,055
Loren J. Miller	19,344,088	37,555
Harold J. Noyes	19,344,088	37,555

PART II

ITEM 5 Market Price Of The Registrant's Common Stock And Related Security Holder Matters

On October 29, 2003, shares of Tri-Valley Corporation stock began trading on the American Stock Exchange under the symbol "TIV". Prior to that, shares had been traded over-the-counter on the Electronic Bulletin Board under the symbol "TRIL." The following table shows the high and low sales prices reported on AMEX for the year ended December 31, 2004 as well as for the period from 10/29/03 to 12/31/03, and the high and low bid and asked prices of Tri-Valley stock for the quarterly periods indicated as reported by the OTC Stock Journal:

		Sales Prices		Closing Prices
		High	Low	High	Low
2004
	Fourth Quarter	$12.98	$4.40	$12.23	$4.46
	Third Quarter	$4.70	$3.73	$4.70	$3.89
	Second Quarter	$4.94	$3.90	$4.91	$3.98
	First Quarter	$5.40	$4.30	$5.40	$4.36

		Bid Prices		Asked Prices
		High	Low	High	Low
2003
	Fourth Quarter	$6.20	$3.44	$6.75		$3.35
	Third Quarter	$3.74	$2.90	$3.93		$2.95
	Second Quarter	$3.79	$1.21	$4.20		$1.21
	First Quarter	$1.60	$1.25	$1.67		$1.21

As of December 31, 2004, we estimate that our common stock was held by approximately 4,500 shareholders in 40 states and at least 4 foreign countries.

We historically have paid no dividends and at this time do not plan to pay any dividends in the immediate future. Rather, we strive to add share value through discovery success. In 2004 trading volume exceeded 8.2 million shares.

Recent Sales of Unregistered Securities

The Company issued 41,000 shares of common stock without registration under the Securities Act of 1933. One former employee exercised stock options for 10,000 shares on October 15, 2004 and 11,000 shares on December 14, 2004. The exercise price of the stock options was $0.50 per share, granted in 1993 and the options were exercised on two occasions when the closing price of our common stock was $4.64 and $7.09 per share. On December 24, 2004, a total of 20,000 shares were awarded to five outside directors for services. The closing price of our common stock on December 23, 2004, was $9.86 per share. All of these shares issued in privately negotiated transactions in reliance on the exemption contained in Section 4(2) of the Securities Act.

7

ITEM 6 Selected Historical Financial Data

	Year Ended December 31,
	2004	2003	2002	2001	2000
Income Statement Data:	(restated)	(restated)
Revenues	$   4,498,670	$   6,464,245	$   6,284,908	$   2,130,187	$   2,197,369
Operating Income (Loss)	$(1,171,005)	$     456,109	$       769,130	$     (117,972)	$  (1,360,263)
Basic Earnings Per Share	$           (.06)	$             .02	$               .04	$              -	$          (0.07)
Balance Sheet Data:
Property and Equipment, net	$   1,778,208	$   1,543,121	$   1,974,501	$   2,010,457	$   1,357,959
Total Assets	$ 14,473,326	$   8,341,782	$   4,634,874	$   3,381,757	$   4,053,257
Long Term Obligations	$          6,799	$        16,805	$        26,791	$          8,371	$        12,038
Stockholder's Equity	$   6,796,903	$   1,851,783	$   1,262,306	$      353,776	$      391,651

ITEM 7 Management's Discussion And Analysis Of Financial Condition

Notice Regarding Forward-Looking Statements

This report contains forward-looking statements. The words, "anticipate," "believe," "expect," "plan," "intend," "estimate," "project," "could," "may," "foresee," and similar expressions are intended to identify forward-looking statements. These statements include information regarding expected development of the Company's business, lending activities, relationship with customers, and development in the oil and gas industry. Should one or more of these risks or uncertainties occur, or should underlying assumptions prove incorrect, actual results may vary materially and adversely from those anticipated, believed, estimated or otherwise indicated.

Overview

Production from TVOG's existing reserves continues to decline, while demand increases. While the trend for demand to outstrip available supplies is worldwide as well as national, we believe that it is particularly acute in California, our primary venue for exploration and production, which imports nearly 60% of its oil and nearly 90% of its natural gas demand. Oil prices tend to be set based on worldwide supplies and prices, while natural gas prices seem to be more dependent on local conditions. We expect that gas prices will hold steady or possibly increase over this year. If, however, prices should fall, for instance due to new regulatory measures or the discovery of new and easily producible reserves, our revenue from oil and gas sales would also fall.

In 2002 we created a limited partnership called the Opus-I. The purpose of this partnership is to raise one hundred million dollars by selling partnership interests. With the funds raised we will drill up to twenty-six exploratory wells, mostly in California, of which three are targeted for Nevada. We begin drilling for the Opus I partnership as sufficient funds are invested to drill the next target. For the year ended December 31, 2004, we have raised $9,173,550 and spent $6,861,245 on evaluating previously drilled wells on the Oil Creek, Oil Lake and Elk Ridge prospects. We have determined to abandon these wells. Additionally, in 2004 we drilled one well on the Los Gatos prospect which was a dry hole and was abandoned.

Tri-Valley continues grading and prioritizing our geologic library, which contains over 700 California leads and prospects, for exploratory drilling. We use our library to decide where we should seek oil and gas leases for future exploration. From this library we were able to put together many of the prospects currently in Opus-I. Of course, we cannot be sure that any future prospect can be obtained at an attractive lease price or that any exploration efforts would result in a commercially successful well.

Tri-Valley seeks to fund and drill enough exploratory wells for commercial discoveries to make up for the cost of the inevitable dry holes that we can expect in the exploration business. The Company believes our existing inventory of projects bears a high enough ratio of potentially successful to unsuccessful projects to deliver value to our drilling partners and our shareholders from successful wells, in excess of the total costs of all successful and unsuccessful projects. Our future results will depend on our success in finding new reserves and commercial production, and there can be no assurance what revenue we can ultimately expect from any new discoveries. Tri-Valley Corporation

8

does not engage in hedging activities and does not use commodity futures or forward contracts for cash management functions.

Restatements

Management discovered in 2005 that the stocks issued to the board of directors were inadvertently over-priced at the end of 2004 for total of $105,000. As the result the Company restated its 2004 financial statement to correct this error.

During 2004, the Company documented and tested its system of internal controls in compliance with Sarbanes-Oxley Section 404. From this activity, management determined its historic accounting procedures, surrounding revenue and cost recognition for its sales and performance surrounding turnkey drilling, were no longer appropriate and required an adjustment for fiscal year 2003 and the first two quarters for fiscal 2004. Management therefore reported that its financial statements for the year 2003, and for the first and second quarters of 2004 should no longer be relied upon because of these pending restatements. The restatements decreased net income approximately $704,000 for the year ended December 31, 2003, increased net income by approximately $799,000 for the quarter ended March 31, 2004 and approximately $1,240,000 for the quarter ended June 30, 2004. The restatements for the December 31, 2003, 10-K and the quarter ended March 31, 2004 result from a change in revenue recognition policy. The restatement for the second quarter ended June 30, 2004 was due to the discovery of an expense that had been double charged and has now been corrected. Management determined these mismatching and accounting errors, which resulted in the restatements, were caused by a significant deficiency in internal control over financial reporting. In the third quarter of 2004, management implemented procedures to prevent this in the future,See Item 9A, Controls and Procedures.

The Company receives monies from third parties who participate in drilling oil and gas wells and records this as revenue. Previously we recognized revenue and associated costs when the well was begun, as long as drilling was completed by close of books based on accrual accounting. At the end of fiscal 2003, we began drilling a turnkey well, which was taken to total depth by January 8, 2004. Although we had collected all payment for the drilling by December 31, 2003, we had not completely performed the turnkey contract to total depth until after December 31, 2003. Because the collected turnkey revenue was essentially nonrefundable, we had recorded the entire turnkey revenue and its associated drilling costs before the close of books based on accrual accounting rather than the date certain of the close of the fiscal year on December 31. Upon review of this practice, to remove all doubt, we now believe turnkey revenue and associated costs should be recorded when the well is drilled to total targ et depth and/or logged. We have changed our revenue recognition policy to recognize these payments as revenue only when drilling is actually completed and the well has been logged within the actual dates of the fiscal/calendar year. This change caused reported drilling revenue and related costs in 2003 to decrease and reported revenue and related costs in 2004 to increase. Additionally, reported revenue for the June 30, 2004 quarter increased approximately $441,000 due to a double entry of an expense. During management's review of internal controls the double entry was discovered and the adjustment resulted in the increase in fiscal 2004 earnings.

The anticipated changes discussed above do not affect the Company's ongoing cash flows.

Critical Accounting Policies

We prepare Consolidated Financial Statements for inclusion in this Report in accordance with accounting principles that are generally accepted in the United States ("GAAP").Note 3 to our Consolidated Financial Statements (contained in Item 8 of this Annual Report) contains a comprehensive discussion of our significant accounting policies. Critical accounting policies are those that may have a material impact on our financial statements and also require management to exercise significant judgment due to a high degree of uncertainty at the time the estimate is made. Our senior management has discussed the development and selection of our accounting policies, related accounting estimates and disclosures with the Audit Committee of our Board of Directors.

Successful Efforts Method Of Accounting

The Company utilizes the successful efforts method of accounting for oil and gas activities as opposed to the alternate acceptable full cost method. In general, the Company believes that, during periods of active exploration,

9

net assets and net income are more conservatively measured under the successful efforts method of accounting for oil and gas producing activities than under the full cost method. The critical difference between the successful efforts method of accounting and the full cost method of accounting is as follows: Under the successful efforts method, exploratory dry holes and geological and geophysical exploration costs are charged against earnings during the periods in which they occur; whereas, under the full cost method of accounting, such costs and expenses are capitalized as assets, pooled with the costs of successful wells and charged against the earnings of future periods as a component of depletion expense.

Use of Estimates

Preparation of our Consolidated Financial Statements under GAAP requires management to make estimates and assumptions that affect reported assets, liabilities, revenues, expenses, and some narrative disclosures. The estimates that are most critical to our Consolidated Financial Statements involve oil and gas reserves, recoverability and impairment of reserves, and useful lives of assets.

Oil and Gas Reserve Estimates.Estimates of our proved reserves included in this Report are prepared in accordance with GAAP and SEC guidelines and were based on evaluations audited by independent petroleum engineers with respect to our major properties. The accuracy of a reserve report estimate is a function of:

- The quality and quantity of available data;

- The interpretation of that data;

- The accuracy of various mandated economic assumptions; and

- The judgment of the persons preparing the estimate.

Because these estimates depend on many assumptions, all of which may substantially differ from future actual results, reserve estimates will be different from the quantities of oil and gas that are ultimately recovered. In addition, results of drilling, testing and production after the date of an estimate may justify material revisions to the estimate.

In 2004 and 2004, our proved, developed gas reserve estimates were revised downward by a total of approximately 490 million cubic feet. These downward revisions were the result of reducing the potential future recoverable reserves from a single well. Production data indicated that the initial reserve estimates would not be achievable, so reserve estimates were reduced accordingly.

It should not be assumed that the present value of future net cash flows included in this Report as of December 31, 2004 is the current market value of our estimated proved reserves. In accordance with SEC requirements, we have based the estimated present value of future net cash flows from proved reserves on prices and costs on the date of the estimate. Actual future prices and cost may be materially higher or lower than the prices and costs as of the date of the estimate.

Estimates of proved reserves materially impact depletion expense. If the estimates of proved reserves decline, the rate at which we record depletion expense will increase, reducing future net income. Such a decline may result from lower market prices, which may make it uneconomic to drill for and produce higher cost fields. In addition, a decline in proved reserve estimates may impact the outcome of our assessment of its oil and gas producing properties for impairment.

Impairment of Proved Oil and Gas Properties. We review our long-lived proved properties, consisting of oil and gas reserves, at least annually and record impairments to those properties, whenever management determines that events or circumstances indicate that the recorded carrying value of the properties may not be recoverable. Proved oil and gas properties are reviewed for impairment by depletable field pool, which is the lowest level at which depletion of proved properties are calculated. Management assesses whether or not an impairment provision is necessary based upon its outlook of future commodity prices and net cash flows that may be generated by the properties. We determine that a property is impaired when prices being paid for oil or gas make it no longer profitable to drill on, or to continue production on, that property. Price increases over that past three years have reduced the instances where impairment of reserves appeared to be required, though we did record impairment expense of $112,395 in 2004 as a result of reducing potential future recoverable reserves from a single well.

10

Additional production data indicated the initial reserve estimates would not be achievable, so we reduced reserves accordingly. If petroleum prices, particularly natural gas prices, in Northern California, begin to fall in the future, more of our proved developed reserves could become impaired, which would reduce our estimates of future revenue, our proved reserve estimates and our profitability.

Asset Retirement Obligations.We adopted SFAS No. 143, "Accounting for Asset Retirement Obligations" effective January 1, 2003. Under this guidance, management is required to make judgments based on historical experience and future expectations regarding the future abandonment cost of its oil and gas properties and equipment as well as an estimate of thin e discount rate to be used in order to bring the estimated future cost to a present value. The discount rate is based on the risk free interest rate which is adjusted for our credit worthiness. The adjusted risk free rate is then applied to the estimated abandonment costs to arrive at the obligation existing at the end of the period under review. We review our estimate of the future obligation quarterly and accrue the estimated obligation based on the above.

Other Significant Accounting Policies

In addition to those significant accounting policies described in Note 3 to our Consolidated Financial Statements, we have adopted the following accounting policies which may require the use of estimates.

Deferred Tax Asset Valuation Allowances. We maintain a valuation allowance against our deferred tax assets, which result from net operating losses and statutory depletion carryforwards from prior years. We continually assess whether it is more likely than not that deferred tax assets can be realized prior to their expiration, but we currently have a valuation allowance of 100% of the value of the deferred tax assets.See Note 8 to our Consolidated Financial Statements.

Commitments and contingencies. We make judgments and estimates regarding possible liabilities for litigation and environmental remediation. We have no ongoing litigation. We routinely have clean-up and maintenance obligations in connection with oil and gas drilling and production activities, but we have never had a material environmental liability or claim. See Note 12 to our Consolidated Financial Statements.

Goodwill. We evaluate goodwill at least annually in December. At December 31, 2004, goodwill, which consists of purchased assets of our subsidiary, TVOG, constituted less than 2% of our total assets.See Note 3 - Goodwill - of our Consolidated Financial Statements.

Petroleum Activities

The Company generally sells a percentage of production at the monthly spot price. In times when we expect the price of gas to weaken, we try to increase the amount we sell under fixed prices. When we expect the price of gas to rise, we seek to sell more gas in the spot market. In 2004, 2003 and 2002, we sold our gas 100% on the spot market. Because we expect gas prices to rise, we intend to sell 100% of our production on the spot market in 2005. Thus, a drop in the price of gas in 2005 could possibly have a more adverse impact on us than if we entered into some fixed price contracts for sale of future production.

Our proved hydrocarbon reserves were valued using a standardized measure of discounted future net cash flows of $1,958,238 at December 31, 2004, compared to $2,270,632 and $2,224,270 on December 31, 2003 and 2002, respectively, after taking into account a 10% discount rate and also taking into consideration the effect of income tax. This reduction was due primarily to the declines in production rates from our existing wells, which have not been supplemented with new discoveries. Estimates such as these are subject to numerous uncertainties inherent in the estimation of quantities of proved reserves. Because of unpredictable variances in expenses and capital forecasts, crude oil and natural gas price changes, largely influenced and controlled by U.S. and foreign government actions, and the fact that the basis for such estimates vary significantly, management believes the usefulness of these projections is limited. Estimates of future net cash flows presen ted do not represent management's assessment of future profitability or future cash flows to the Company. This value does not appear on the balance sheet because accounting rules require discovered reserves to be carried on the balance sheet at the cost of obtaining them rather than the actual future net revenue from producing them. Tri-Valley typically has no discovery cost to put on the balance sheet as explained below.

11

Tri-Valley sold working interests in its test wells on prospects to the Opus-1 drilling partnership. The sales price of the interest is intended to pay for all drilling and testing costs on the property. Tri-Valley retains a minority "carried" ownership interest in the well and does not pay its proportionate share of drilling and testing costs for the first well drilled on each prospect. However, the Company does pay its proportionate cost of any subsequent well drilled on each prospect. Under these arrangements, we usually minimize the Company's cost to drill and also receive a minority interest from the reserves we discover. On the other hand, we occasionally incur extra expenses for drilling or development that we choose, in our discretion, not to pass on to other venture participants.

In 2003 we drilled the Oil Creek, Oil Lake and Elk Ridge Prospects. After thorough review it was determined the prospects would not be commercially successful and will be abandoned. In 2004 we drilled the Los Gatos prospect which was a dry hole and was abandoned.

We fraced the deep Ekho well and redrilled a horizontal test of the Sunrise-Mayel #2 in the first quarter of 2005.

Mining Activity

The price of gold has fluctuated between $374 and $438 per ounce rekindling interest of investors to support junior exploration ventures. Accordingly, management implemented its plan to establish a wholly owned subsidiary to handle all mining business for eventual spin off to Tri-Valley shareholders.

The Company began the buyout of royalty and carried working interest burdens on its Richardson, Alaska gold exploration project in order to transfer the property into our new subsidiary, Select Resources Corporation, free of royalty burdens. Tri-Valley Corporation expects to record substantial non cash losses as a result of issuing stock for these interests which are non producing at this time and cannot be booked as assets equal to the value of the stock paid. The Company believes the ultimate return it can realize on the property unburdened by royalty and carried interests will handily exceed the upfront costs of the buyout.

Select Resources Corporation is initially staffed by F. Lynn Blystone, Chairman and CEO, Dr. Harold J. Noyes, President, Dr. Henry J. "Rick" Sandri, Executive Vice President, Thomas J. Cunningham, Chief Financial Officer, Dr. Odin Christensen, consulting geologist and technical team leader, Dr. Craig Beagle, consulting geophysicist, Dr. Jeffrey Jaecks, consulting geochemist and Sandra Perry, consulting remote sensing specialist.

In December 2004, Select Resources acquired another gold/copper property in Alaska, the 5,000 acre Shorty Creek Prospect near Livengood some 70 miles north of Fairbanks on the Dalton Highway pipeline haul road. Select has recently completed staking another 5,300 acres of claims adjoining and speculated to be on trend with mapped mineralization of the initial claim block acquisition. There are no proven reserves at this time. Select plans extensive prospecting on Shorty Creek and drilling on one or more targets on Richardson in this 2005 season. Tri-Valley advanced to Select $500,000 for geological and geophysical mapping and drilling.

Select's most ambitious initial effort has been the establishment and operation of the Alpha Minerals and Chemicals LLC joint venture to mine, process and sell high chemical grade-high whitener calcium carbonate from the Monarch Mine in eastern Kern County, California. Select is in the process of refining a business plan and establishing operations in 2005. Select is the operator of the 50-50 joint venture with Trans Western Materials, a privately held Nevada LLC that owns the mineral leases. Select's business objective is to establish a positive cash flow to help support its exploration activities. Select's parent, Tri-Valley Corporation has committed $2.5 million to establish the joint venture with Trans Western Materials contributing its leases and business relationships.

Results of Operations

The Company lost $1,171,005 in 2004 compared to profits of $456,109 in 2003 and $769,130 in 2002. Total revenue was $1,965,575 lower in 2004 than in 2003.

12

Revenues

In 2004, 2003 and 2002, our largest source of revenue has been oil and gas drilling and development. We record revenue received by us from joint ventures for drilling and development when we complete drilling wells that have been sold to venture partners, including the Opus-I drilling partnership sponsored by Tri-Valley. In 2004, our revenue from drilling and development fell to about $3.56 million, compared to $5.44 million in 2003 and $5.42 million in 2002. In 2004 we recorded drilling and development revenues from drilling only one well, compared to revenues recorded from drilling three wells in 2003 and drilling two wells and recompleting one well in 2002. We expect that our 2005 from drilling activity and consequent income will equal or exceed 2004. However, we do not develop annual drilling budgets but drill according to availability of funds and equipment to drill prospects that we consider attractive.

Our drilling activities are also affected by factors beyond our control, such as availability of drilling equipment and delays in the regulatory permitting process to drill new wells. In 2004, unavailability of drilling equipment caused us to drill fewer wells than we had originally expected to drill that year. We expect to drill more wells as a smaller cost per well in 2005, but unavailability of drilling equipment continues to create delays in beginning project s in northern California and may curtail our drilling activity for the rest of 2005 below the level that we otherwise could comfortably manage and afford.

Our natural gas production continued to decline in 2004, with total gas production down 22% from 2003 and 45% from 2002 levels. However, because of continuing natural gas price increases our revenues from sales of oil and gas remained relatively stable, declining only 11% from 2003 and rising 6% from 2002 revenues. We have not added significant producing reserves for the past two years, and in addition to normal declines in production over time, two wells that produced in 2003 have been shut in since early 2004 and remain shut in as of the date of this amended report. We are considering whether these two wells can be reworked to restart production in commercial quantities. In the first half of 2005 production continued to decline by another 22% from production in the first half of 2004, and we expect that gas production for 2004 will continue to be below 2004 levels and that total revenues realized from that production will also be lower for 2005 than 2004, despite the continuing rise in gas prices. If gas prices were to once again fall, our revenues would, of course, fall even further. We cannot predict what our total production of oil and gas will be in 2005.

We also derive a small amount of revenue from interest income received on cash from equity investments and cash advanced from joint venture partners. Interest income rose by 33% in 2004 over 2003 as we increased the amount of cash held pending investment in oil and gas and other projects. Interest income has continued to rise in the first half of 2005 and will likely be higher in 2005 than 2004, though it may fall as we expend funds on drilling projects. Interest income is, however, a relatively insignificant part of our total revenues (about 1% in 2004).

Costs and Expenses

Because of our reduced drilling activity in 2004, our drilling and development costs also fell. Our 2004 drilling and development costs fell 45% from 2003 and 39% from 2002 expenditures. As with drilling and development revenue, against which these drilling and development costs are incurred, we expect that drilling and development costs will remain about the same in 2005 as 2004 or increase slightly, but our expenditures for these activities are subject to the same uncertainties as described above for drilling and development revenue.

Likewise, oil and gas lease expense fell as our production activity fell in 2004, mainly due to having two shut in wells for much of 2004, for which we incurred fewer operating costs. We expect that oil and gas producing activities in 2005 will remain below 2004 as these wells continue to be shut in and, in the first half of 2005, we brought no new wells into production. Likewise, depreciation, depletion and amortization expense fell in 2004 compared to 2003 and 2002 due to lower production levels, but this is a minor component of our current operating costs.

We evaluate our oil and gas properties regularly for possible impairment. In 2004, we wrote down our proved reserves by $112,395 as a result of reducing the potential future recoverable reserves from a single well, based on our analysis of production data from that well. We recorded no impairment expense in 2003 and had a $45,143

13

write-down for impairment in 2002. Due to the unpredictable nature of exploration drilling activities, the amount and timing of impairment expenses are difficult to predict with any certainty

Our lower costs of drilling and development and oil and gas production in 2004 were counterbalanced by rises in mining exploration costs and general and administrative expenses. We recorded just over $1 million for mining exploration in 2004, a rise of more than 180% from 2003 and 500% from 2002, because we recorded $804,000 in costs of issuance of our common stock to repurchase royalty interests that we had previously sold in our Richardson, Alaska gold claims. We repurchased these interests in order to make the claims more attractive for outside investors to either acquire the claims or to invest jointly with us in their development. During 2005, we are seeking outside investments to develop these claims, and in the first half of 2005 we recorded an additional $2.01 million in expense from issuance of restricted common stock issued to reacquire more royalty interests in the Richardson property. We expect that we may continue to incur costs to reacquire additional royalty interests as well a s other precious metals interests in Alaska during 2005, but we do not have a budgeted or projected amount for these acquisitions.

General and administrative expenses rose by about $730,000 (53%) in 2004 over 2003, to about $2.10 million, compared to about $1.37 million in 2003 and $1.32 million in 2002. The increase resulted from small increases in several administrative areas, but chiefly were caused by increased legal costs associated with payment of a judgment and other costs of a lawsuit in 2004 (approximately $186,000), increased payroll and consulting costs for consultants and directors' fees (up $160,000) and more than $100,000 in direct costs associated with the acquisition of our industrial minerals interests late in the year. Travel and investor relation expense rose over $107,000 in 2004 over 2003. Insurance costs rose by about $48,000 and insurance costs rose by nearly $34,000, both of which costs we attribute to increased costs of compliance with the Sarbanes-Oxley Act and attendant increases in directors' officers' insurance. The costs associated with the judgment were a one-time expense. General and admin istrative expenses can be expected to continue to rise in 2005 because of costs associated with the start-up of Select Resources and beginning industrial mineral production, which we have not incurred in prior years. These costs include increased payroll, equipment acquisition and direct expenses to be incurred in mining, plus continued increases in accounting costs associated with compliance with the Sarbanes-Oxley Act.

Financial Condition

Balance Sheet

At December 31, 2004 we had $11,812,920 in cash compared to $6,006,975 for December 31, 2003. This represents, for the most part, cash invested by the Opus I partners for the drilling of oil and gas wells in that limited partnership. Property and equipment is $235,087 more for the current period compared to last year because of increased leasehold interest acquired. Deposits decreased $171,698 in 2004 compared to 2003 due to the settlement of a lawsuit and the payment of the award, which was secured by a bond.

Commitments

Generally, our financial commitments arise from selling interests in our drilling prospects to third parties, which results in an obligation to drill and develop the prospect. If we are unable to sell sufficient interests in a prospect to fund its drilling and development, we must either amend our agreements to drill the prospect, locate a substitute prospect acceptable to the participants or refund the participants' funds.

The Company sponsored Opus I, a private placement drilling program intended to raise up to one hundred million dollars to drill and complete 26 prospects. We turnkey the drilling portion and the completion portion is based on costs incurred. In a turnkey program we guarantee to drill a well(s) for a certain amount. If the drilling amount is greater than the turnkey costs the Company would lose money on that well, if the cost is less than the turnkey costs the Company would make a profit on that well.

Delay rentals for oil and gas leases amounted to $159,188 in 2004. Advance royalty payments and gold mining claims maintenance fees were $205,555 for the same period. We expect that approximately equal delay rentals and fees will be paid in 2005 from operating revenues.

14

The following schedule summarizes our known contractual cash obligations at December 31, 2004, and the effect such obligations are expected to have on our liquidity and cash flow in future periods. At December 31, 2004, our only long term obligation consisted of a small outstanding loan incurred for automobile loans.

	Total Obligations	2005	2006-2007	2008-2009	Beyond
Long-term debt	$16,784	$9,985	$6799

Operating Activities

Net cash provided by operating activities was $1,023,187 for the year-end December 31, 2004, compared to $3,548,941 for the same period in 2003.Our operating loss of $1.17 million included non-cash charges of $916,000, including $112,000 for impairment of oil and gas property and $804,000 for stock issued to acquire royalty interests in our Richardson, Alaska, gold claim.See, MD&A - Mining Activity, page 12. In addition, our accounts payable increased by $552,064 because at year end we had ongoing drilling and reworking projects which caused a temporary rise in payables. Accounts payable remained at their year end levels during the first quarter of 2005 and decreased during the second quarter as we completed and paid for the drilling and reworking projects on hand. We pay our bills as they come due and expect to continue to do so in the future. Rises in accounts payable such as occurred at 2004 year end are temporary and are nearly al ways attributable to then-current drilling and development activity.

Advances from joint venture participants are funds received from partners in the Opus I drilling partnership and other, similar ventures. These funds rose at the end of 2004 by $1,196,430 over year end 2003 as we held funds received from participants for investment in future drilling. Advances from joint venture participants have continued to rise in 2005 but are expected to decrease as we apply those funds to drilling and development activities. We cannot predict with any certainty the timing of receipt of funds from joint venture participants for future activities. These advances do not contribute to operating income when received but are held until expended for drilling and development and then recorded as drilling and development revenue.

Investing Activities

Cash used by investing activities in 2004 was $519,181 compared to cash provided of $402,164 for the same period in 2003. We used $$369,181 for capital expenditures, including $112,000 for oil and gas prospect acquisitions and $257,181 to purchase equipment for our new Tri-Western mining joint venture. We used $150,000 in 2004 for investment in start-up costs on Tri-Western. We did not realize any proceeds from sales of oil and gas leases to joint ventures in 2004, compared to sales of $401,164 to joint ventures in 2003. Through the first six months of 2005 we greatly increased our investing activities, spending $2.964 million to purchase an oil and gas subsidiary with prospective oil and gas properties and investing about $4 million in our Tri-Western joint venture. We expect that the Tri-Western venture will begin to produce revenue in the third quarter of 2005, but we may need to invest more cash in property and equipment for Tri-Western in the second half of 2005 to meet new demands for products by customers after that project starts to yield products and revenue.

Financing Activities

Cash provided by financing activities was $5,301,939 for the period ending December 31, 2004 compared to $119,576 for the same period in 2003. The financing activities consisted of sales of restricted common stock in private transactions and the exercise of stock options by directors. The proceeds of the stock sales are expected to be used for property acquisitions and working capital. The trend of increased equity investments in our restricted common stock continued in the first half of 2005. We do not have a target amount for raising additional equity in 2005 and cannot predict what our total stock sales may be. Any additional proceeds from equity sales will be added to working capital.

Liquidity

The recoverability of the our oil and gas reserves depends on future events, including obtaining adequate financing for our exploration and development program, successfully completing our planned drilling program, and achieving

15

a level of operating revenues that is sufficient to support our cost structure. At various times in our history, it has been necessary for us to raise additional capital through private placements of equity financing. When such a need has arisen, we have met it successfully. It is management's belief that we will continue to be able to meet our needs for additional capital as such needs arise in the future. We may need additional capital to pay for our share of costs relating to the drilling prospects and development of those that are successful, and to acquire additional oil and gas leases. The total amount of our capital needs will be determined in part by the number of prospects generated within our exploration program and by the working interest that we retain in those prospects.

During 2005, we expect to expend approximately $2.5 million on drilling activities. In the first half of 2005, we spent approximately $1.2 million of this amount. Funds for these activities will be provided by sales of partnership interests in the Opus-I drilling partnership. At June 30, 2005, we had more than enough funds on hand from prior sales of limited partnership units to fund the balance of our drilling activities for 2005. We have not yet planned our proposed prospect drilling and development activities for 2006. Our ability to complete our planned drilling activities in 2005 depends on some factors beyond our control, such as the availability of drilling rigs and equipment, which continue to be in short supply in northern California.

In 2005, we expect expenditures of approximately $3.8 million on mining activities, including mining lease and exploration expenses, in connection with beginning operation of the Monarch Mine in California. We had spent approximately $2.8 million on mining lease and exploration expense in the first half of the year and expect approximately another $1 million in expenses in the remainder of the year, after production at the Monarch Mine begins, to improve our production capacity. The source of these funds has been sales of restricted stock in late 2004 and the first half of 2005. We believe that proceeds from our prior stock sales are more than sufficient to fund our remaining mining activities as well as our operating capital needs for the balance of 2005. We expect that revenue from mining operations will begin to offset mine operating expenses beginning in the third quarter of 2005.

Should we choose to make an acquisition of producing oil and gas properties, such an acquisition would likely require that some portion of the purchase price be paid in cash, and thus would create the need for additional capital. Additional capital could be obtained from a combination of funding sources. The potential funding sources include:

- Cash flow from operating activities,

- Borrowings from financial institutions,

- Debt offerings, which could increase our leverage and add to our need for cash to service such debt,

- Additional offerings of our equity securities, which would cause dilution of our common stock,

- Sales of portions of our working interest in the prospects within our exploration program, which would reduce future revenues from its exploration program,

- Sale to an industry partner of a participation in our exploration program,

- Sale of all or a portion of our producing oil and gas properties, which would reduce future revenues.

Our ability to raise additional capital will depend on the results of our operations and the status of various capital and industry markets at the time such additional capital is sought. Accordingly, there can be no assurances that capital will be available to us from any source or that, if available, it will be on terms acceptable to us.

16

ITEM 8: FINANCIAL STATEMENTS

TRI-VALLEY CORPORATION

INDEX

	Page(s)
Report of Independent Auditor	18
Consolidated Balance Sheets at December 31, 2004 and 2003	19
Consolidated Statements of Operations for the Years Ended
December 31, 2004, 2003 and 2002	21
Consolidated Statements of Changes in Shareholders' Equity for the
Years Ended December 31, 2004, 2003 and 2002	22
Consolidated Statements of Cash Flows for the Years Ended
December 31, 2004, 2003 and 2002	23
Notes to Consolidated Financial Statements	25
Supplemental Information about Oil and Gas Producing
Activities (Unaudited)	43

17

REPORT OF INDEPENDENT REGISTERED

PUBLIC ACCOUNTING FIRM

The Board of Directors

Tri-Valley Corporation

Bakersfield, California

We have audited the accompanying consolidated balance sheets of Tri-Valley Corporation (the "Company") as of December 31, 2004 and 2003 and the related consolidated statements of operations, changes in shareholders' equity and cash flows for each of the three years in the period ended December 31, 2004. These financial statements are the responsibility of the Company's management. Our responsibility is to express an opinion on these financial statements based on our audits.

We conducted our audits in accordance with auditing standards of the Public Company Accounting Oversight Board (United States). Those standards require that we plan and perform the audits to obtain reasonable assurance about whether the financial statements are free of material misstatement. An audit includes examining, on a test basis, evidence supporting the amounts and disclosures in the financial statements. An audit also includes assessing the accounting principles used and significant estimates made by management, as well as evaluating the overall financial statement presentation. We believe that our audits provide a reasonable basis for our opinion.

In our opinion, the consolidated financial statements referred to above present fairly in all material respects the financial position of Tri-Valley Corporation at December 31, 2004 and 2003, and the results of their operations and their cash flows for each of the three years in the period ended December 31, 2004, in conformity with accounting principles generally accepted in the United States of America.

As discussed in Note 2 to the financial statements, certain errors resulting in overstatement of previously reported general and administrative expense for the year ended December 31, 2004 and overstatement of previously reported drilling and development revenue and the related costs for the year ended December 31, 2003, were discovered by management of the Company during the current year. Accordingly, the 2004 and 2003 financial statements have been restated to correct the error.

We also have audited, in accordance with the standards of the Public Company Accounting Oversight Board (United States), the effectiveness of Tri-Valley Corporation's internal control over financial reporting as of December 31, 2004, based on criteria established inInternal Control-Integrated Framework issued by the Committee of Sponsoring Organizations of the Treadway Commission (COSO), and our report dated March 29, 2005 expressed an unqualified opinion on management's assessment of internal control over financial reporting and an adverse opinion on the effectiveness of internal control over financial reporting.

                                                                                BROWN ARMSTRONG PAULDEN

                                                                                McCOWN STARBUCK & KEETER

                                                                                ACCOUNTANCY CORPORATION

Bakersfield, California

March 29, 2005, except for Note 13
whose date is May 30, 2005

18

TRI-VALLEY CORPORATION

CONSOLIDATED BALANCE SHEETS

	December 31,
	2004	2003
ASSETS	(restated)	(restated)
Current assets
Cash	$          11,812,920	$  6,006,975
Accounts receivable, trade	192,008	163,825
Advance receivable	150,000	-
Prepaid expenses	96,056	12,029
Total current assets	12,250,984	6,182,829
Property and equipment, net
Proved properties	131,382	148,482
Unproved properties	1,381,667	1,251,953
Other property and equipment	265,159	142,686
Total property and equipment, net (Note 1 and Note 2)	1,778,208	1,543,121
Other assets
Deposits	200,407	372,105
Investments in partnerships (Note 1)	17,400	17,400
Goodwill	212,414	212,414
Other	13,913	13,913
Total other assets	444,134	615,832
Total assets	$     14,473,326	$  8,341,782

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

19

TRI-VALLEY CORPORATION

CONSOLIDATED BALANCE SHEETS

LIABILITIES AND STOCKHOLDER'S EQUITY
	December 31,
	2004	2003
	(restated)	(restated)
Current liabilities
Notes payable	$            9,985	$         9,985
Income taxes payable	-	39,000
Accounts payable and accrued expenses	1,237,848	685,784
Amounts payable to joint venture participants	100,115	91,275
Advances from joint venture participants, net	6,321,676	5,647,150
Total current liabilities	7,669,624	6,473,194
Non-Current Liabilities
Deferred tax Liability
Long-term portion of notes payable	6,799	16,805
Total non-current liabilities	-	16,805
Total liabilities	7,676,423	6,489,999
Stockholder's equity
Common stock, $.001 par value; 100,000,000 shares
authorized; 21,836,052 and 20,097,627 issued and
outstanding at December 31, 2004, and 2003	21,836	20,115
Less: common stock in treasury, at cost,
100,025 shares at December 31, 2004 and 2003.	(13,370)	(13,370)
Subscription receivable	(750)	-
Capital in excess of par value	15,125,607	9,010,453
Accumulated deficit	(8,336,420)	(7,165,415)
Total stockholder's equity	6,796,903	1,851,783
Total liabilities and stockholder's equity	$  14,473,326	$  8,341,782

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

20

TRI-VALLEY CORPORATION

CONSOLIDATED STATEMENTS OF OPERATIONS

	__For the Years Ended December 31,_
	___2004___	___2003___	___2002___
	(restated)	(restated)
Revenues
Sale of oil and gas	$     799,474	$     901,739	$      752,971
Royalty income	674	529	351
Partnership income	30,000	30,000	18,299
Gain on sale of property		-	-
Interest income	45,990	34,479	19,534
Drilling and development	3,559,500	5,440,780	5,421,782
Other income	63,032	56,718	71,971
Total revenues	4,498,670	6,464,245	6,284,908
Costs and expenses
Mining exploration costs	1,029,898	366,039	169,111
Oil and gas leases	144,101	183,362	224,320
Drilling and development costs	2,224,793	4,014,889	3,648,089
General and administrative	2,103,457	1,373,058	1,316,893
Interest	33,332	2,572	1,838
Depreciation, depletion and amortization	21,699	29,216	34,384
Well write-off		-	-
Impairment of acquisition costs	112,395	-	45,143
Total costs and expenses	5,669,675	5,969,136	5,439,778
Net income (loss) before income taxes	(1,171,005)	495,109	845,130
Tax provision	-	39,000	76,000
Net income (loss)	$ (1,171,005)	$     456,109	$      769,130
Basic and diluted earnings (loss) per common share
and common equivalent share	$          (0.06)	$            0.02	$            0.04
Weighted average number of shares outstanding	20,507,342	19,801,785	19,702,054

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

21

TRI-VALLEY CORPORATION

CONSOLIDATED STATEMENTS OF STOCKHOLDER'S EQUITY

	Total			Capital in	Common
	Common	Treasury		Excess of	Stock	Accumulated	Treasury	Stockholder's
	Shares	Shares	Par Value	Par Value	Receivable	Deficit	Stock	Equity
Balance at December 31, 2002	19,726,348	100,025	$       19,726	$  8,879,724	$     (2,250)	$(7,621,524)	$(13,370)	$1,262,306
Issuance of common stock	371,279	-	389	1,442,439	-	-	-	1,442,828
Stock issuance cost	-	-	-	(1,311,710)	-	-	-	(1,311,710)
Common stock receivable	-	-	-	-	2,250	-	-	2,250
Net income, as restated	-	-	-	-	-	456,109	-	456,109
Balance at December 31, 2003, as restated	20,097,627	100,025	20,115	9,010,453	-	(7,165,415)	(13,370)	1,851,783
Issuance of common stock	1,738,425	-	1,721	6,761,354	-	-	-	6,763,075
Stock issuance cost	-	-	-	(646,200)	-	-	-	(646,200)
Common stock receivable	-	-	-	-	(750)	-	-	(750)
Net loss	-	-	-	-	-	(1,171,005)	-	(1,171,005)
Balance at December 31, 2004,
As restated	21,836,052	100,025	$       21,836	$ 15,125,607	$        (750)	$ (8,336,420)	$  (13,370)	$ 6,796,903

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

22

TRI-VALLEY CORPORATION

CONSOLIDATED STATEMENTS OF CASH FLOWS

	For the Years Ended December 31,
	2004	2003	2002
	(restated)	(restated)
CASH FLOWS FROM OPERATING ACTIVITIES
Net income (loss)	$ (1,171,005)	$   456,108	$  769,130
Adjustments to reconcile net income (loss) to net cash
provided (used) by operating activities:
Depreciation, depletion, and amortization	21,699	29,216	34,384
Impairment, dry hole and other disposals of property	112,395	-	45,143
Land acquisition costs sold	-	-	122,315
(Gain) on sale of property		-	-
Non-employee stock compensation	804,180	-	119,700
Impairment, dry hole and other disposals of property
and equipment		-	-
Changes in operating capital:
(Increase) decrease in accounts receivable	(28,183)	(12,207)	(44,393)
Increase in prepaids		-	-
Increase in deposits and other assets	87,671	(55,400)	(212,000)
Increase (decrease) in income taxes payable	(39,000)	(37,000)	76,000
Increase (decrease) in accounts payable and accrued expenses	552,064	121,544	267,239
Increase (decrease) in amounts payable to joint venture
participants and related parties	8,840	16,863	14,781
Increase (decrease) in advances from joint venture
Participants	674,526	3,029,817	(37,380)
Net Cash Provided by Operating Activities	1,023,187	3,548,941	1,154,919
CASH FLOWS FROM INVESTING ACTIVITIES
Proceeds from sale of property	-	402,164	-
Capital expenditures	(369,181)	-	(184,185)
(Investment in) advance to joint project	(150,000)	-	-
(Investment in) distribution from partnerships	-	-	10,000
Net Cash Provided (Used) by Investing Activities	(519,181)	402,164	(174,185)
CASH FLOWS FROM FINANCING ACTIVITIES
Proceeds from long-term debt	-	-	29,686
Principal payments on long-term debt	(10,006)	(13,792)	(5,739)
Net Proceeds from issuance of common stock	5,310,224	133,368	19,700
Sale of treasury stock	-	-	-
Stock issuance costs	-	-	-
Net Cash Provided by Financing Activities	5,301,939	119,576	43,647

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

23

TRI-VALLEY CORPORATION

CONSOLIDATED STATEMENTS OF CASH FLOWS

	For the Years Ended December 31,
	2004	2003	2002
	(restated)	(restated)
Net Increase (Decrease) in Cash and Cash Equivalents	$  5,805,945	$  4,070,681	$  1,024,381
Cash at Beginning of Year	6,006,975	1,936,294	911,913
Cash at End of Year	$11,812,920	$ 6,006,975	$ 1,936,294
Interest paid	$       33,332	$        2,572	$        1,838
Income taxes paid	$                 -	$      40,000	$           800

SUPPLEMENTAL NON-CASH ACTIVITIES:

Services paid with common stocks	$       92,200	$   23,247	$            -
Stock issued to exchange mining claims	$       712,000	$             -	$            -

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

24

TRI-VALLEY CORPORATION

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

December 31, 2004 and 2003 and 2002

NOTE 1 - GENERAL

History and Business Activity

Tri-Valley Corporation ("TVC" or the Company), a Delaware corporation formed in 1971, is in the business of exploring, acquiring and developing petroleum and precious metals properties and interests therein. Tri-Valley has three wholly owned subsidiaries. Tri-Valley Oil & Gas Company ("TVOG") operates the oil & gas activities, and derives the majority of its revenue from oil and gas drilling and development. Tri-Valley Power Corporation and Select Resources are the other two wholly owned subsidiaries which have minimum activities during 2004.

The Company conducts its oil and gas business primarily through Tri-Valley Oil & Gas Company. TVOG is engaged in the exploration, acquisition and production of oil and gas properties. Substantially all of the Company's oil and gas reserves are located in northern California. In the fiscal year 1987, the Company added precious metals exploration. At present, the precious metals exploration activities are conducted directly by the parent, Tri-Valley Corporation. TVC has traditionally sought acquisition or merger opportunities within and outside of petroleum and mineral industries.

For purposes of reporting operating segments, the Company is involved in three areas. These are drilling and development, oil and gas production, and precious metals.

NOTE 2 - RESTATEMENT

2004 Restatement

Management discovered in 2005 that the stocks issued to the board of directors were inadvertently over-priced at the end of 2004 for total of $105,000. As the result the Company restated its 2004 financial statement to correct this error.

The following sets forth the significant effects of the aforementioned restatements to the Company's consolidated financial statements for the fiscal year ended December 31, 2004:

	As Previously		As
	Reported	Adjustment	Restated
General and administrative	2,208,457	(105,000)	2,103,457
Total Cost and Expenses	5,774,675	(105,000)	5,669,675
Net income (loss)	(1,276,005)	105,000	(1,171,005)
Capital in excess of par value	15,230,607	(105,000)	15,125,607
Accumulated deficit	(8,441,420)	105,000	(8,336,420)

2003 Restatement

Management determined that its accounting procedures for revenue and costs related to turnkey drilling were no longer appropriate and required an adjustment for the fiscal year ended 2003 and the first two quarters for fiscal 2004.

The restatements for the year ended December 31, 2003 resulted from a change in the Company's revenue recognition policy. The Company previously recognized revenues on turnkey drillings before the close of the books because full payment had been collected and the amounts were non refundable. The Company changed its revenue recognition policy to book revenue only when the well is drilled to its target depth and/or logged.

25

TRI-VALLEY CORPORATION

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

December 31, 2004 and 2003 and 2002

NOTE 2 - RESTATEMENT (continued)

2003 Restatement (continued)

This change has caused drilling revenue and the related costs to decrease during the year ended December 31, 2003 and increase in the first quarter of the year ended December 31, 2004.

The restatement for the quarter ended June 30, 2004 relates to the correction of an expense that was originally double booked. The adjustment has resulted in an increase of earnings

The following sets forth the significant effects of the aforementioned restatements to the Company's consolidated financial statements for the fiscal year ended December 31, 2003:

	As Previously		As
	Reported	Adjustment	Restated	Reference
Sales of oil and gas prospects	$    6,585,780	$ 1,145,000)	$  5,440,780	[1]
Total Revenues	7,609,245	(1,145,000)	6,464,245
Cost of oil and gas prospects sold	4,360,679	(345,790)	4,014,889	[2]
General and administrative	1,449,589	(76,531)	1,373,058	[3]
Total Cost and Expenses	6,391,463	(422,327)	5,969,136
Net income (loss) before income tax	1,217,782	(722,673)	495,109
Tax provision	58,000	(19,000)	39,000	[4]
Net Income (Loss)	1,159,782	(664,673)	456,109
Basic and diluted earnings (loss) per
common share and common equivalent	0.06	(0.04)	0.02
Property and Equipment, Net	$     1,522,333	$       20,788	$  1,543,121	[5]
Total Assets	8,320,992	20,790	8,341,782
Income tax payable	58,000	(19,000)	39,000	[4]
Accounts payable & accrued expenses	777,729	(91,945)	685,784	[3]
Advances from joint venture participants	4,811,742	835,408	5,647,150	[6]
Total Current Liabilities	5,748,731	724,463	6,473,194
Total liabilities	5,765,536	724,463	6,489,999
Accumulated deficit	(6,461,742)	(703,673)	(7,165,415)	[7]
Total Shareholders' Equity	2,555,456	(703,673)	1,851,783
Total Liabilities and Shareholders' Equity	8,320,992	20,790	8,341,782

       The restatements to the financial statements for the year ended December 31, 2003 are due to:

1.  Recognition of revenues related to turnkey drilling of $1,145,000 was deferred to 2004 when oil or gas well was drilled to its target depth and/or logged.

26

TRI-VALLEY CORPORATION

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

December 31, 2004 and 2003 and 2002

NOTE 2 - RESTATEMENT (continued)

2003 Restatement (continued)

2.	This amount of cost of oil and gas prospects was erroneously omitted in the previously filed statements of operations, although it was included in the total cost.
3.	Certain general and administration costs associated with the deferred turnkey revenue were also deferred to match with the revenue recognition.

NOTE 3 - SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES

This summary of significant accounting policies of Tri-Valley Corporation is presented to assist in understanding the Company's financial statements. The financial statements and notes are representations of the Company's management, which is responsible for their integrity and objectivity. These accounting policies conform to accounting principles generally accepted in the United States of America and have been consistently applied in the preparation of the financial statements.

Principles of Consolidation

The consolidated financial statements include the accounts of the Company and its wholly-owned subsidiaries, Tri-Valley Oil & Gas Co. and Selected Resources. All material intercompany accounts and transactions have been eliminated in consolidation.

Use of Estimates in the Preparation of Financial Statements

The preparation of financial statements in conformity with accounting principles generally accepted in the United States of America requires management to make estimates and assumptions that affect the reported amounts of assets, liabilities and disclosures at the date of the financial statements as well as the reported amounts of revenues and expenses during the reporting period. Actual results could differ from those estimates.

Material estimates that are particularly susceptible to significant change relate to the estimate of Company oil and gas reserves prepared by an independent engineering consultant. Such estimates are subject to numerous uncertainties inherent in the estimation of quantities of proved reserves.

Estimated reserves are used in the calculation of depletion, depreciation and amortization as well as the Company's assessment of proved oil and gas properties for impairment.

Cash Equivalent and Short-Term Investments

Cash equivalents include cash on hand and on deposit, and highly liquid debt instruments with original maturities of three months or less. The majority of these funds are held at Smith Barney.

Goodwill

The consolidated financial statements include the net assets purchased of Tri-Valley Corporation's wholly owned oil and gas subsidiary, TVOG. Net assets are carried at their fair market value at the acquisition date. On January 1, 2002, Tri-Valley Corporation adopted Financial Accounting Standards Board (FASB) Statement of Financial Accounting Standards (SFAS) No. 142, "Goodwill and Other Intangible Assets" (SFAS 142). Under SFAS 142, goodwill is a non-amortizable asset, and is subject to a periodic review for impairment. Prior to the implementation of SFAS 142, the Company had goodwill of $433,853 that was being amortized. The carrying amount of goodwill is evaluated annually in December of each year. Factors used in the evaluation include the Company's ability to raise capital as a public company and anticipated cash flows from operating and non-operating mineral properties. Based on management's evaluation, no impairment has been applied to the carrying amount of goodwill f or the years ended December 31, 2002, 2003, and 2004.

27

TRI-VALLEY CORPORATION

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

December 31, 2004 and 2003 and 2002

NOTE 3 - SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Continued)

Advances from Joint Venture Participants

Advances received by the Company from joint venture partners for contract drilling projects, which are to be spent by the Company on behalf of the joint venture partners, are classified within operating inflows on the basis they do not meet the definition of financing or investing activities. When the cash advances are spent, the payable is reduced accordingly. These advances do not contribute to the Company's operating profits and are accounted or/disclosed as balance sheet entries only i.e. within cash and payable to joint venture participants.

Revenue Recognition

Sale of Oil and Gas

Crude oil and natural gas revenues are recognized as production occurs, the title and risk of loss transfers to a third party purchaser, net of royalties, discounts, and allowances, as applicable.

Sale of Oil and Gas Prospects

Oil and gas prospects are developed by the Company for sale to industry partners and investors. These prospects are usually exploratory, and include costs of leasing, acquisition, and other geological and geophysical costs (hereafter referred to as "GGLA") plus a profit to the Company. Prior to 2002, the Company recognized revenue and profit from prospect sales when sold, irrespective of drilling commencement ("spudding").

Starting 2002 the Company changed its prospect offerings by inclusion of estimated costs of drilling in addition to GGLA costs. This offering is termed a "turnkey" exploratory drilling opportunity because investors are charged only one certain amount in return for Tri-Valley drilling a well to the agreed total depth.

Once the well is spudded, investor money is not refundable. Tri-Valley recognizes revenue when the well is logged. Amounts charged are included in an Authority for Expenditure (AFE), which is a budget for each project well. Tri-Valley prepares the AFE and bears all risk of well completion to total depth. If the well is drilled to total depth for actual costs less than the AFE amounts, the Company realizes a profit. Conversely, if actual costs exceed the AFE, Tri-Valley realizes a loss.

Drilling Agreements/Joint Ventures

Tri-Valley frequently participates in drilling agreements whereby it acts as operator of drilling and producing activities. As operator, TVOG is liable for the activities of these ventures. In the initial well in a prospect, the Company owns a carried interest and/or overriding royalty interest in such ventures, earning a working interest upon commencement of drilling. Costs of subsequent wells drilled in a prospect are shared by a pro rata interest.

Receivables from and amounts payable to these related parties (as well as other related parties) have been segregated in the accompanying financial statements. For turnkey projects, amounts received for drilling activities, which have not been spudded are deferred and remain within the joint venture liability, in accordance with the Company's revenue recognition policies. Revenue is recognized upon the completion of drilling operations and the well is logged. Actual or estimated costs to complete the drilling are charged as costs against this revenue.

Oil and Gas Property and Equipment (Successful Efforts)

The Company accounts for its oil and gas exploration and development costs using the Successful Efforts Method. Under this method, costs to acquire mineral interests in oil and gas properties, to drill and complete exploratory wells that find proved reserves and to drill and complete development wells are capitalized. Exploratory dry-hole costs, geological and geophysical costs and costs of carrying and retaining unproved

28

TRI-VALLEY CORPORATION

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

December 31, 2004 and 2003 and 2002

NOTE 3 - SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Continued)

Oil and Gas Property and Equipment (Successful Efforts, continued)

properties are expensed when incurred, except those GGLA expenditures incurred on behalf of joint venture drilling projects, which the Company defers until the GGLA is sold at the completion of project funding and the target prospect is drilled. Expenditures incurred in drilling exploratory wells are accumulated as work in process until the Company determines whether the well has encountered commercial oil and gas reserves.

If the well has encountered commercial reserves, the accumulated cost is transferred to oil and gas properties; otherwise, the accumulated cost, net of salvage value, is charged to dry hole expense. If the well has encountered commercial reserves but cannot be classified as proved within one year after discovery, then the well is considered to be impaired, and the capitalized costs (net of any salvage value) of drilling the well are charged to expense. In 2004, 2003, and 2002 there was $112,395, $0, and $45,143 respectively, charged to expense for impairment of exploratory well costs. Depletion, depreciation and amortization of oil and gas producing properties are computed on an aggregate basis using the units-of-production method based upon estimated proved developed reserves.

At December 31, 2004 and 2003, the Company carried unproved property costs of $1.381 million and $1.252 million, respectively. Generally accepted accounting principles require periodic evaluation of these costs on a project-by-project basis in comparison to their estimated value. These evaluations will be affected by the results of exploration activities, commodity price outlooks, planned future sales or expiration of all or a portion of the leases, contracts and permits appurtenant to such projects. If the quantity of potential reserves determined by such evaluations is not sufficient to fully recover the cost invested in each project, the Company will recognize non cash charges in the earnings of future periods.

Capitalized costs relating to proved properties are depleted using the unit-of-production method based on proved reserves. Costs of significant non-producing properties, wells in the process of being drilled and development projects are excluded from depletion until such time as the related project is completed and proved reserves are established or, if unsuccessful, impairment is determined.

Upon the sale of oil and gas reserves in place, costs less accumulated amortization of such property are removed from the accounts and resulting gain or loss on sale is reflected in operations. Impairment of non-producing leasehold costs and undeveloped mineral and royalty interests are assessed periodically on a property-by-property basis, and any impairment in value is currently charged to expense.

In addition, we assess the capitalized costs of unproved properties periodically to determine whether their value has been impaired below the capitalized costs. We recognize a loss to the extent that such impairment is indicated. In making these assessments, we consider factors such as exploratory drilling results, future drilling plans, and lease expiration terms. When an entire interest in an unproved property is sold, gain or loss is recognized, taking into consideration any recorded impairment. When a partial interest in an unproved property is sold, the amount is treated as a reduction of the cost of the interest retained, with excess revenue and carrying costs being recognized. Upon abandonment of properties, the reserves are deemed fully depleted and any unamortized costs are recorded in the statement of operations under leases sold, relinquished and impaired.

Gold Mineral Property

The Company has invested in several gold mineral properties with exploration potential. All mineral claim acquisition costs and exploration and development expenditures are charged to expense as incurred. We capitalize acquisition and exploration costs only after persuasive engineering evidence is obtained to support recoverability of these costs (ideally upon determination of proven and/or probable reserves based upon dense drilling samples and feasibility studies by a recognized independent engineer). Currently no amounts have been capitalized.

29

TRI-VALLEY CORPORATION

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

December 31, 2004 and 2003 and 2002

NOTE 3 - SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Continued)

Other Properties and Equipment

Properties and equipment are depreciated using the straight-line method over the following estimated useful lives:

Office furniture and fixtures Building 3 - 7 years 40 years

Leasehold improvements are amortized over the life of the lease.

Maintenance and repairs, which neither materially add to the value of the property nor appreciably prolong its life, are charged to expense as incurred. Gains or losses on dispositions of property and equipment other than oil and gas are reflected in operations.

Concentration of Credit Risk and Fair Value of Financial Instruments

As discussed in Note 9, the Company sells oil, gas and natural gas liquids to primarily one purchaser located in the northern California region.

The Company places its temporary cash investments with high credit quality financial institutions and limits the amount of credit exposure to any one financial institution.

Fair value of financial instruments is estimated to approximate the related book value, unless otherwise indicated, based on market information available to the Company.

Stock Based Compensation Plans

The Company has adopted only the disclosure requirements of SFAS No. 123, Accounting for Stock-Based Compensation, and has elected to continue to record stock-based compensation expense using the intrinsic-value approach prescribed by Accounting Principles Board ("APB") Opinion 25. The application of APB Opinion 25 has further been clarified by Financial Accounting Standards Board ("FASB") Interpretation No. 44, "Accounting for Certain Transactions involving Stock Compensation". Under APB No. 25, because the exercise price of the company's employee stock options equals the market price of the underlying stock on the date of grant, no compensation expense is recognized. However, SFAS No. 123, "Accounting for Stock-Based Compensation," requires presentation of pro forma information as if the company had accounted for its employee stock options and performance awards granted subsequent to December 31, 1994, under the fair value of that statement.

For purposes of pro forma disclosure, the estimated fair value of the options and performance awards at the date of grant is charged to expense as the employee stock options are fully vested upon grant. Under the fair value method, the company's net income (loss) and earnings (loss) per share would have been as follows:

30

TRI-VALLEY CORPORATION

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

December 31, 2004 and 2003 and 2002

NOTE 3 - SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Continued)

Stock Based Compensation Plans (continued)

		December 31,	December 31,	December 31,
		2004	2003	2002
		(restated)	(restated)
Net Income	As reported	$    (1,171,005)	$      496,109	$        769,130
	Pro forma	(1,171,005)	399,009	769,130
Earnings per share	As reported	(0.06)	0.02	0.04
	Pro forma	(0.06)	0.01	0.04
Diluted earnings per share	As reported	(0.06)	0.02	0.04
	Pro forma	(0.06)	0.01	0.03

Reclassification

Certain amounts in the financial statements have been reclassified to be consistent and comparable from year-to-year.

Treasury Stock

The Company records acquisition of its capital stock for treasury at cost. Differences between proceeds for reissuance of treasury stock and average cost are charged to retained earnings or credited thereto to the extent of prior charges and thereafter to capital in excess of par value.

Recently Issued Accounting Pronouncements

In April 2002, the FASB issued SFAS No. 145, "Rescission of FASB Statements No. 4, 44 and 64, Amendment of FASB Statement No. 13 and Technical Corrections". SFAS 145, which is effective for fiscal years beginning after May 15, 2002, provides guidance for income statement classification of gains and losses on extinguishment of debt and accounting for certain lease modifications that have economic effects that are similar to sale-leaseback transactions. The adoption of this statement did not impact the Company's financial position, results of operations, or cash flows.

In June 2002, the FASB issued SFAS No. 146, "Accounting for Costs Associated with Exit or Disposal Activities." SFAS 146 nullifies the guidance of the Emerging Issues Task Force (EITF) Issue No. 94-3, "Liability Recognition for Certain Employee Termination Benefits and Other Costs to Exit an Activity (including Certain Costs Incurred in a Restructuring)." SFAS 146 requires that a liability for a cost that is associated with an exit or disposal activity be recognized when the liability is incurred. SFAS 146 also establishes that fair value is the objective for the initial measurement of the liability. The provisions of SFAS 146 are required for exit or disposal activities that are initiated after December 31, 2003. The adoption of this statement did not impact the Company's financial position, results of operations, or cash flows.

In December 2002, the FASB issued SFAS No. 148, "Accounting for Stock-Based Compensation - Transition and Disclosure." SFAS 148 amends FASB Statement No. 123, "Accounting for Stock-Based Compensation" to provide alternative methods of transition for a voluntary change to the fair value based method of accounting for stock-based employee compensation. In addition, this Statement amends the disclosure requirements of Statement 123 to require prominent disclosures in both annual and interim financial statements about the method of accounting for stock-based employee compensation and the effect of the method used on the reported

31

TRI-VALLEY CORPORATION

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

December 31, 2004 and 2003 and 2002

NOTE 3 - SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Continued)

Recently Issued Accounting Pronouncements (continued)

results. The provisions of SFAS 148 are effective for financial statements for fiscal years ending after December 15, 2002. The adoption of this statement did not impact the Company's financial position, results of operations, or cash flows.

During January 2003, the Financial Accounting Standards Board issued interpretation No. 46, "Consolidation of Variable Interest Entities" ("FIN46"), which requires the consolidation of certain entities that are determined to be variable interest entities ("VIE's"). An entity is considered to be a VIE when either (i) the entity lacks sufficient equity to carry on its principal operations, (ii) the equity owners of the entity cannot make decisions about the entity's activities or (iii) the entity's equity neither absorbs losses or benefits from gains.

In November 2004, the FASB issued SFAS No. 151, "Inventory Costs". SFAS No. 151 amends the accounting for abnormal amounts of idle facility expense, freight, handling costs, and wasted material (spoilage) under the guidance in ARB No. 43, Chapter 4,"Inventory Pricing". Paragraph 5 of ARB No. 43, Chapter 4, previously stated that ". . . under some circumstances, items such as idle facility expense, excessive spoilage, double freight, and rehandling costs may be so abnormal as to require treatment as current period charges. . . ." This Statement requires that those items be recognized as current-period charges regardless of whether they meet the criterion of "so abnormal." In addition, this Statement requires that allocation of fixed production overheads to the costs of conversion be based on the normal capacity of the production facilities. This statement is effective for inventory costs incurred during fiscal years beginning after June 15, 2005. Management does not expect adop tion of SFAS No. 151 to have a material impact on the Company's financial statements.

In December 2004, the FASB issued SFAS No. 152, "Accounting for Real Estate Time-Sharing Transactions". The FASB issued this Statement as a result of the guidance provided in AICPA Statement of Position (SOP) 04-2,"Accounting for Real Estate Time-Sharing Transactions". SOP 04-2 applies to all real estate time-sharing transactions. Among other items, the SOP provides guidance on the recording of credit losses and the treatment of selling costs, but does not change the revenue recognition guidance in SFAS No. 66, "Accounting for Sales of Real Estate", for real estate time-sharing transactions. SFAS No. 152 amends Statement No. 66 to reference the guidance provided in SOP 04-2. SFAS No. 152 also amends SFAS No. 67, "Accounting for Costs and Initial Rental Operations of Real Estate Projects", to state that SOP 04-2 provides the relevant guidance on accounting for incidental operations and costs related to the sale of real estate time-sharing transactions. SFAS No. 152 is effective for years beginning after June 15, 2005, with restatements of previously issued financial statements prohibited. This statement is not applicable to the Company.

In December 2004, the FASB issued SFAS No. 153, "Exchanges of Nonmonetary Assets," an amendment to Opinion No. 29, "Accounting for Nonmonetary Transactions". Statement No. 153 eliminates certain differences in the guidance in Opinion No. 29 as compared to the guidance contained in standards issued by the International Accounting Standards Board. The amendment to Opinion No. 29 eliminates the fair value exception for nonmonetary exchanges of similar productive assets and replaces it with a general exception for exchanges of nonmonetary assets that do not have commercial substance. Such an exchange has commercial substance if the future cash flows of the entity are expected to change significantly as a result of the exchange. SFAS No. 153 is effective for nonmonetary asset exchanges occurring in periods beginning after June 15, 2005. Earlier application is permitted for nonmonetary asset exchanges occuring in periods beginning after December 16, 2004. Management does not expect adoption of SFAS No. 153 to have a material impact on the Company's financial statements.

In December 2004, the FASB issued SFAS No. 123(R), "Share-Based Payment" which amends SFAS No. 123, "Accounting for Stock-Based Compensation", and APB Opinion 25, "Accounting for Stock Issued to Employees." SFAS No.123(R) requires that the cost of share-based payment transactions (including those with

32

TRI-VALLEY CORPORATION

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

December 31, 2004 and 2003 and 2002

NOTE 3 - SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Continued)

Recently Issued Accounting Pronouncements (Continued)

employees and non-employees) be recognized in the financial statements. SFAS No. 123(R) applies to all share-based payment transactions in which an entity acquires goods or services by issuing (or offering to issue) its shares, share options, or other equity instruments (except for those held by an ESOP) or by incurring liabilities (1) in amounts based (even in part) on the price of the entity's shares or other equity instruments, or (2) that require (or may require) settlement by the issuance of an entity's shares or other equity instruments. This statement is effective (1) for public companies qualifying as SEC small business issuers, as of the first interim period or fiscal year beginning after December 15, 2005, or (2) for all other public companies, as of the first interim period or fiscal year beginning after June 15, 2005, or (3) for all nonpublic entities, as of the first fiscal year beginning after December 15, 2005. Management is currently assessing the effect of SFA S No. 123(R) on the Company's financial statement.

Sarbanes-Oxley Act Of 2002

Section 404 of the Sarbanes-Oxley Act of 2002 requires public Companies to report on both internal control over financial reporting and disclosure controls and procedures. Internal control over financial reporting refers to:

(a)	controls to ensure that a Company's information systems record financial information that allows the Company to issue fair and accurate financial statements;
(b)	controls that ensure against unauthorized receipts and expenditures; and
(c)	controls to prevent and detect unauthorized acquisition, use or disposition of the assets.

Disclosure controls and procedures refer to controls that ensure that all information that must be reported to the Securities and Exchange Commission is received by management on a timely basis.

NOTE 4 - PROPERTY AND EQUIPMENT

Oil and gas properties, and equipment and fixtures consist of the following:

	December 31,
	2004	2003
Oil and gas - California
Proved properties, gross	$          752,705	$          752,705
- accumulated depletion	(621,323)	(604,223)
Proved properties, net	131,382	148,482
Unproved properties	1,381,667	1,251,953
Total oil and gas properties	1,513,049	1,400,435

33

TRI-VALLEY CORPORATION

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

December 31, 2004 and 2003 and 2002

NOTE 4 - PROPERTY AND EQUIPMENT (Continued)

	December 31
	2004	2003
Other property and equipment
Land	12,281	12,281
Building	50,395	50,395
Transmission tower	45,000	45,000
Office equipment, vehicle, and leasehold improvements	345,586	218,514
	453,262	326,190
Accumulated depreciation	(188,103)	(183,504)
Total other property and equipment, net	265,159	142,686
Property and equipment, net	$       1,778,208	$       1,543,121

NOTE 5 - NOTES PAYABLE

	December 31,
	2004	2003
Note payable to Union Bank dated July 29,2002;
secured by a vehicle; interest at 8.3%; payable
in 60 monthly installments of $602.	$           12,452	$           22,437
Note payable to Union Bank, dated January
15, 2000; secured by a vehicle; interest at 8.5%;
Payable in 60 monthly installments of $380.	4,332	4,353
	16,784	26,790
Less current portion	9,985	9,985
Long-term portion of notes payable	$            6,799	$          16,805

Maturities of long-term debt for the years subsequent to December 31, 2004 are as follows:

2005	$                 9,985
2006	2,721
2007	4,078
	$               16,784

34

TRI-VALLEY CORPORATION

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

December 31, 2004 and 2003 and 2002

NOTE 6 - RELATED PARTY TRANSACTIONS

Employee Stock Options

The Company has a qualified and a nonqualified stock option plan, which provides for the granting of options to key employees, consultants, and nonemployee directors of the Company.

The option price, number of shares and grant date are determined at the discretion of the Company's board of directors. Options granted under the plans are exercisable immediately; however, the plan expires in August 2008.

The purpose of the Company's stock option plans is to further the interest of the Company by enabling officers, directors, employees, consultants and advisors of the Company to acquire an interest in the Company by ownership of its stock through the exercise of stock options and stock appreciation rights granted under its various stock option plans.

The fair value of each option grant is estimated on the date of grant the Black-Scholes American option-pricing model with the following weighted-average assumptions used for grant in 2003 and 2002, respectively. There were no options granted in 2004.

Year	Expected Life	ExpectedDividends	ExpectedVolatility	Risk-Free Interest Rates
2003	4	None	88%	3.00
2002	5	None	98.04%	3.86

A summary of the status of the Company's fixed stock option plan as of December 31, 2004, 2003 and 2002 and changes during the years ending on those dates is presented below:

	2004		2003		2002
		Weighted-		Weighted-		Weighted-
		Average		Average		Average
		Exercise		Exercise		Exercise
	Shares	Price	Shares	Price	Shares	Price
Fixed Options
Outstanding at beginning of year	3,018,600	$          1.27	2,960,500	$        1.25	3,229,000	$         1.26
Granted	-	-	100,000	$        1.33	-	$           -
Exercised	(465,000)	$           1.20	(41,900)	$        0.50	(20,500)	$         0.50
Cancelled	-	$               -	-	$             -	(248,000)	$         1.36
Outstanding at end of year	2,553,600	$           1.28	3,018,600	$       1.27	2,960,500	$         1.25
Options exercisable at year-end	2,553,600		3,018,600		2,960,500
Weighted-average fair value of options granted during the year
	n/a		$            0.96		n/a
Available for issuance	390,000
			35

TRI-VALLEY CORPORATION

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

December 31, 2004 and 2003 and 2002

NOTE 6 - RELATED PARTY TRANSACTIONS (Continued)

Employee Stock Options (continued)

The following table summarizes information about fixed stock options outstanding at December 31, 2004:

	Options Outstanding and Exercisable
		Weighted-Average
	Number Outstanding	Remaining	Weighted-Average
Range of Exercise Prices	at December 31, 2004	Contractual Life	Exercise Price
$.50 - $2.43	2,553,600	3.72	$1.28

Partnerships

Tri-Valley sells oil and gas prospects to partnerships that are sponsored by Tri-Valley and sold to private investors for the purpose of oil and gas drilling and development. The Company accounts for these partnerships on the prorate combination method. Drilling and development revenue related to the Opus-I and Martins-Severin partnerships for the fiscal year ended December 31, 2004, 2003 and 2002 are as follows:

	December 31,
	2004	2003	2002
Drilling and development revenue	$ 3,559,500	$ 5,440,780	$ 4,421,782
Drilling and development costs	2,224,793	4,014,889	3,648,089
Advances from joint venture   participants, net	6,321,676	5,647,150	5,617,333

Oil and gas income from the Tri-Valley Oil & Gas Exploration Programs 1971-1 for fiscal 2004, 2003 and 2002 follows:

	December 31,
	2004	2003	2002
Partnership income, net of expenses	$      30,000	$      30,000	$     18,299

NOTE 7 - EARNINGS PER SHARE

Year	Full Year Basic Earnings (Loss) PerShare	Weighted-Average SharesOutstanding	Diluted Earnings (Loss) PerShare	Diluted Earnings Weighted-Average Share Outstanding Plus Common Stock Equivalents	Common Stock Equivalents Excluded from Diluted EarningsPer Share
2004	$    (0.06)	20,507,342	$    (0.06)	2,553,600	$           -
2003	0.02	19,801,785	0.02	3,018,600	-
2002	0.04	19,702,054	0.03	2,698,500	960,000

The diluted earning per share amounts are based on weighted-average shares outstanding plus common stock equivalents. Common stock equivalents include stock options and awards, and common stock warrants.

36

TRI-VALLEY CORPORATION

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

December 31, 2004 and 2003 and 2002

Common stock equivalents excluded from the calculation of diluted earnings per share due to the effect was antidilutive.

NOTE 8 - INCOME TAXES

At December 31, 2004, the Company had available net operating loss carry forwards for financial statements and federal income tax purposes of approximately $2 million.

The components of the net deferred tax assets were as follows

:

	December 31,	December 31,	December 31,
	2004	2003	2002
	(restated)	(restated)
Deferred tax assets:
Net operating loss carryforwards	$          776,000	$          345,727	$           45,667
Statutory depletion carryforwards	356,000	339,007	297,217
Total deferred tax assets	1,132,000	684,734	342,884
Valuation allowance	(1,132,000)	(684,734)	(342,884)
Net deferred tax assets	$                      -	$                      -	$                    -

A full valuation allowance has been established for the deferred tax assets generated by net operating loss and statutory depletion carryforwards due to the uncertainty of future utilization. The net operating loss expires in 2022 for federal purposes and 2023 for state purposes. Depletion carryforwards have an indefinite life.

The reconciliation of federal taxable income follows:

	December 31,	December 31,	December 31,
	2004	2003	2002
	(restated)	(restated)
Income (loss) before tax	$    (1,171,005)	$      495,109	$        845,130
Computed "expected" tax (benefit)	$     (398,000)	$        168,000	$        304,344
State tax liability	-	39,000	76,000
Utilization (non-utilization) of operating loss carryover	398,000	(168,000)	(304,344)
Total income tax provision	$                  -	$          39,000	$          76,000

37

TRI-VALLEY CORPORATION

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

December 31, 2004 and 2003 and 2002

NOTE 9 - MAJOR CUSTOMERS

Oil and Gas

Substantially all oil and gas sales have occurred in the northern California gas market.

The Company received substantially all of its oil and gas revenue from one customer. The oil and gas sales to this one customer amounted to $799,474, $901,739, and $752,971 for the year ended December 31, 2004, 2003, and 2002, respectively.

NOTE 10 - FINANCIAL INFORMATION RELATING TO INDUSTRY SEGMENTS

The Company reports operating segments according to SFAS No. 131, "Disclosure About Segments of an Enterprise and Related Information".

The Company identifies reportable segments by product. The Company includes revenues from both external customers and revenues from transactions with other operating segments in its measure of segment profit or loss. The Company also includes interest revenue and expense, DD&A, and other operating expenses in its measure of segment profit or loss.

The Company's operations are classified into three principal industry segments. Following is a summary of segmented information for 2004, 2003, and 2002:

	Oil and Gas	Precious	Drilling and
	Production	Metals	Development	Total
Year ended December 31, 2004
Revenues from external customers	$       830,148	$                  -	$     3,559,500	$    4,389,648
Interest revenue	$         45,990	$                  -	$                  -	$         45,990
Interest expense	$         33,332	$                  -	$                  -	$         33,332
Expenditures for segment assets	$       369,181	$                  -	$                  -	$       369,181
Depreciation, depletion, and amortization	$         21,699	$                  -	$                  -	$         21,699
Total assets	$  14,473,326	$                  -	$                  -	$  14,473,326
Estimated income tax benefit(expense)	$       160,000	$       412,000	$       (62,000)	$     512,000
Net income (loss)	$    (400,046)	$ (1,029,898)	$       258,939	$ (1,171,005)

38

TRI-VALLEY CORPORATION

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

December 31, 2004 and 2003 and 2002

NOTE 10 - FINANCIAL INFORMATION RELATING TO INDUSTRY SEGMENTS (Continued)

	Oil and Gas	Precious	Drilling and
	Production	Metals	Development	Total
Year ended December 31, 2003			(restated)	(restated)
Revenues from external customers	$       932,268	$                  -	$    5,440,780	$    6,373,048
Interest revenue	$         34,479	$                  -	$                   -	$         34,479
Interest expense	$           2,572	$                  -	$                   -	$          2,572
Expenditures for segment assets	$                  -	$                  -	$                   -	$                  -
Depreciation, depletion, and amortization	$        29,216	$                  -	$                   -	$       29,216
Total assets	$   8,320,992	$                  -	$                   -	$  8,341,782
Estimated income tax benefit(expense)	$      250,000	$      146,000	$     (579,000)	$    (183,000)
Net income (loss)	$     (624,280)	$     (366,039)	$    1,446,428	$     456,109
Year ended December 31, 2002
Revenues from external customers	$      771,621	$                  -	$    5,421,782	$    6,193,403
Interest revenue	$        19,534	$                  -	$                   -	$         19,534
Interest expense	$          1,838	$                  -	$                   -	$           1,838
Expenditures for segment assets	$      155,132	$                  -	$                   -	$       155,132
Depreciation, depletion, and amortization	$        34,384	$                  -	$                   -	$         34,384
Total assets	$   4,634,874	$                  -	$                   -	$    4,634,874
Estimated income tax benefit(expense)	$      334,000	$        68,000	$        (709,000)	$     (307,000)
Net income (loss)	$     (835,452)	$    (169,111)	$     1,773,693	$       769,130

39

TRI-VALLEY CORPORATION

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

December 31, 2004 and 2003 and 2002

NOTE 11 - COMMON STOCK

During 2004 the Company issued the following shares of common stock. All of these securities were issued pursuant to privately negotiated transactions in reliance on the exemption contained in Section 4(2) of the Securities Act.

-   One private individual purchased 1,090,000 common stock shares for total $5,385,000 during the year: 300,000 shares at $4.5 per share, 200,000 shares at $4.75 per share, and 500,000 shares at $5.0 per share, and 90,000 shares at $6.5 per share

-   Another private individual purchased 3,000 shares at $4.05 per share.

-   Companies issued 160,000 shares to two individuals to exchange mining claims in Alaska. The stocks were valued at $4.45 per share at the time of the exchange.

-   The Company issued total 20,000 shares to directors of the Company for services rendered during the year. At the time of the issuance the stocks were valuated at $4.6 per share.

-   During the year various directors and employees of the Company exercised stock options previously granted. The new shares issued pursuant to the stock option plan amounted to 465,000 shares. Cash consideration received totaled to $560,000.

-   During the year the common stock issuance cost amounted to approximately $646,200.

During 2003 we issued the following shares of common stock. All of these securities were issued pursuant to privately negotiated transactions in reliance on the exemption contained in Section 4(2) of the Securities Act.

-   One officer, one former employee, and one private individual exercised options to purchase 41,900 common shares at $.50 each.

-   One private individual purchased 3,000 common stock shares at $1.35 each.

-   The Company issued 15,000 shares to the Company's officers. The closing market price of our common stock on the date we awarded these shares was $1.36.

-   The Company issued 50,000 shares to the Company's outside directors. The closing market price of our common stock on the date we awarded these shares was $1.33

-   The Company issued 6,000 shares to a consultant for service. The closing market price of our common stock on the date we awarded these shares was $3.20.

-   The Company issued 255,387 common shares to Swartz Private Equity, LLC.

NOTE 12 - COMMITMENTS AND CONTINGENCIES

Contingencies

The Company is subject to possible loss contingencies pursuant to federal, state and local environmental laws and regulations. These include existing and potential obligations to investigate the effects of the release of certain hydro-carbons or other substances at various sites; to remediate or restore these sites; and to compensate

40

TRI-VALLEY CORPORATION

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

December 31, 2004 and 2003 and 2002

NOTE 12 - COMMITMENTS AND CONTINGENCIES (Continued)

Contingencies (continued)

others for damages and to make other payments as required by law or regulation. These obligations relate to sites owned by the Company or others, and are associated with past and present oil and gas operations.

The amount of such obligations is indeterminate and will depend on such factors as the unknown nature and extent of contamination, the unknown timing, extent and method of remedial actions which may be required, the determination of the Company's liability in proportion to other responsible parties, and the state of the law.

Natural Gas Contracts

The Company sells its gas under three separate gas contracts. Each of the contracts is effective for a twelve-month period and is renegotiated annually. During 2004, 2003, and 2002, the Company sold all of its produced gas under these agreements. The terms of the agreements are identical among the contracts. During 2004, 2003, and 2002, the terms of the agreements were as follows: 100% of the produced gas was sold at the monthly spot price.

Joint Venture Advances

As discussed in Note 1, the Company receives advances from joint venture participants, which represent funds raised to drill exploratory wells. The Company receives a carried working interest if the well is successfully drilled and completed. The Company acts as both the fiduciary agent and Operator during the period required to drill and equip the well, and as Operator while the well is produced. The Company is obligated to use these funds for expenditures of the joint venture prospect. The joint venture agreements specify that the Company must drill the subject well or substitute another prospect. Some agreements require that the interest earned on joint venture advances be credited to the project account. Expenditures of the projects are charged directly against the obligation.

The balance of the joint venture advance represents the sum of amounts contributed for drilling prospects, net of expenditures for the projects. Residual project balances are held until the Company makes a final determination concerning any remedial obligations of the joint ventures. The balance at December 31, 2004 consists primarily of the following projects:

Opus

In May of 2001 the Company began raising funds for a one hundred million dollar exploration drilling program named Opus-I. The program calls for the drilling of 26 prospects, 23 in California and 3 in Nevada. As of December 31, 2004 the program has drilled ten wells in which nine were dry holes, the remaining wells are currently being tested or evaluated for further work. The drilling portion of these prospects is turn-keyed, meaning the drilling portion is done for a fixed cost and the completion portion is done at the actual cost.

The Opus Drilling Program joint venture status at December 31, 2004 is as follows:

Total Opus Contributions	$        28,940,988
Total Opus Expenditures	$        22,772,733
Advances	$          6,168,255

Ekho

The Ekho project was originally a three-well project, which commenced February 7, 2000 with the first well. The first well has been drilled to its target depth of just over 19,000 feet. The original majority joint

41

TRI-VALLEY CORPORATION

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

December 31, 2004 and 2003 and 2002

NOTE 12 - COMMITMENTS AND CONTINGENCIES (Continued)

Joint Venture Advances (continued)

interest partners were unable to fulfill their obligations to continue to fund well completion activities. The Company is currently seeking substitute partners to raise funds to fracture and complete the well. Ekho joint venture project status at December 31, 2004, which is included in the joint venture advance, is as follows (the vast majority of expenditures were made in 2000):

Total Ekho joint venture contributions	$        10,604,300
Total Ekho joint venture expenditures	$        10,878,236
Interest credited to the joint account	$             246,749

Leases

The Company leases its office space on a month to month basis.

NOTE 13 - SUBSEQUENT EVENTS

On May 6, 2005, the Company acquired Pleasant Valley Energy Corporation, a private holder of leases estimated to contain about 22.658 million barrels of proven undeveloped oil reserves.

42

SUPPLEMENTAL INFORMATION (unaudited)

43

SUPPLEMENTAL INFORMATION (unaudited)

The following estimates of proved oil and gas reserves, both developed and undeveloped, represent interests owned by the Company located solely in the United States.

Disclosures of oil and gas reserves, which follow, are based on estimates prepared by independent engineering consultants for the years ended December 31, 2004, 2003, and 2002. Such analyses are subject to numerous uncertainties inherent in the estimation of quantities of proved reserves and in the projection of future rates of production and the timing of development expenditures. These estimates do not include probable or possible reserves.

These estimates are furnished and calculated in accordance with requirements of the Financial Accounting Standards Board and the Securities and Exchange Commission ("SEC"). Because of unpredictable variances in expenses and capital forecasts, crude oil and natural gas price changes, largely influenced and controlled by U.S. and foreign government actions, and the fact that the basis for such estimates vary significantly, management believes the usefulness of these projections is limited. Estimates of future net cash flows presented do not represent management's assessment of future profitability or future cash flows to the Company. Management's investment and operating decisions are based upon reserve estimates that include proved reserves as well as probable reserves, and upon different price and cost assumptions from those used here.

It should be recognized that applying current costs and prices and a 10 percent standard discount rate does not convey fair market value. The discounted amounts arrived at are only one measure of the value of proved reserves.

Capitalized costs relating to oil and gas producing activities and related accumulated depletion, depreciation and amortization were as follows:

	December 31,	December 31,	December 31,
	2004	2003	2002
		(restated)
Aggregate capitalized costs:
Proved properties	$          752,705	$          752,705	$         752,705
Unproved properties	1,381,667	1,251,953	1,654,117
Accumulated depletion, depreciation and amortization	(621,323)	(604,223)	(587,030)
Net capitalized assets	$       1,513,049	$       1,400,435	$      1,819,792

44

      Supplemental Information (unaudited)

      Page Two

The following sets forth costs incurred for oil and gas property acquisition, exploration and development activities, whether capitalized or expensed, during:

	December 31,	December 31,	December 31,
	2004	2003	2002
		(restated)
Acquisition of producing properties and productive and non-productive acreage	$                     -	$                     -	$                   -
Exploration costs and development activities	$                     -	$                     -	$          45,143

Results Of Operations From Oil And Gas Producing Activities

The results of operations from oil and gas producing activities are as follows:

	December 31,	December 31,	December 31,
	2004	2003	2002
		(restated)
Sales to unaffiliated parties	$           830,148	$           932,268	$           771,621
Production costs	(144,101)	(183,362)	(224,320)
Depletion, depreciation and amortization	(17,100)	(26,551)	(24,719)
	668,947	722,355	522,582
Income tax expense	(240,820)	(264,968)	(187,057)
Results of operations from activities before
extraordinary items (excluding corporate
overhead and interest costs)	$           161,096	$           457,387	$           335,525

45

       Supplemental Information (unaudited)

       Page Three

Changes In Estimated Reserve Quantities

The net interest in estimated quantities of proved developed and undeveloped reserves of crude oil and natural gas at December 31, 2004, 2003, and 2002, and changes in such quantities during each of the years then ended, were as follows:

	December 31, 2004		December 31, 2003		December 31, 2002
			(restated)
	Oil	Gas	Oil	Gas	Oil	Gas
	(BBL)	(MCF)	(BBL)	(MCF)	(BBL)	(MCF)
Proved developed and undeveloped reserves:
Beginning of year	162	1,251,548	150	1,492,245	164	1,684,757
Revisions of previous estimates	-	(374,408)	37	(115,365)	15	40,066
Net reserve additions	-	-	-	36,982	-	-
Production	-	(134,739)	(25)	(162,314)	(29)	(232,578)
End of year	162	742,401	162	1,251,548	150	1,492,245
Proved developed reserves:
Beginning of year	162	1,251,548	150	1,492,245	164	1,684,757
End of year	162	742,401	162	1,251,548	150	1,492,245

Standardized Measure Of Discounted Future Net Cash Flows Relating To Proved Oil And Gas Reserves

A standardized measure of discounted future net cash flows is presented below for the year ended December 31, 2004, 2003, and 2002.

The future net cash inflows are developed as follows:

(1)	Estimates are made of quantities of proved reserves and the future periods during which they are expected to be produced based on year-end economic conditions.
(2)	The estimated future production of proved reserves is priced on the basis of year-end prices.
(3)	The resulting future gross revenue streams are reduced by estimated future costs to develop and to produce proved reserves, based on year end cost estimates.

46

       Supplemental Information (unaudited)

       Page Four

Standardized Measure Of Discounted Future Net Cash Flows Relating To Proved Oil And Gas Reserves (Continued)

(4) The resulting future net revenue streams are reduced to present value amounts by applying a ten percent discount.

Disclosure of principal components of the standardized measure of discounted future net cash flows provides information concerning the factors involved in making the calculation. In addition, the disclosure of both undiscounted and discounted net cash flows provides a measure of comparing proved oil and gas reserves both with and without an estimate of production timing. The standardized measure of discounted future net cash flows relating to proved reserves reflects income taxes.

	December 31,	December 31,	December 31,
	2004	2003	2002
		(restated)
Future cash in flows	$      5,248,091	$    5,973,197	$    5,791,416
Future production and development costs	(989,549)	(1,376,902)	(1,297,906)
Future income tax expenses	(1,357,948)	(1,134,811)	(1,202,626)
Future net cash flows	2,900,595	3,461,484	3,290,884
10% annual discount for estimated timing of cash flows	942,358	1,190,852	1,066,614
Standardized measure of discounted future net cash flow	$      1,958,238	$    2,270,632	$    2,224,270

* Refer to the following table for analysis in changes in standardized measure.

Changes In Standardized Measure Of Discounted Future Net Cash Flow From Proved Reserve Quantities

This statement discloses the sources of changes in the standardized measure from year to year. The amount reported as "Net changes in prices and production costs" represents the present value of changes in prices and production costs multiplied by estimates of proved reserves as of the beginning of the year. The "accretion of discount" was computed by multiplying the ten percent discount factor by the standardized measure as of the beginning of the year. The "Sales of oil and gas produced, net of production costs" is expressed in actual dollar amounts. "Revisions of previous quantity estimates" is expressed at year-end prices.

47

       Supplemental Information (unaudited)

       Page Five

Changes In Standardized Measure Of Discounted Future Net Cash Flow From Proved Reserve Quantities (Continued)

The "Net change in income taxes" is computed as the change in present value of future income taxes.

	December 31,	December 31,	December 31,
	2004	2003	2002
		(restated)
Standardized measure - beginning of period	$       2,270,632	$      2,224,270	$      1,005,010
Sales of oil and gas produced, net of production costs	(655,373)	(748,906)	(547,301)
Revisions of estimates of reserves provided in prior years:
Net changes in prices	1,705,515	969,281	2,432,433
Revisions of previous quantity estimates	-	(171,355)	166,536
Extensions and discoveries	270,891	102,382	-
Purchases of minerals in place	-	-	-
Accretion of discount	248,494	263,451	274,545
Changes in production rates (timing) and other	(1,658,785)	(436,306)	(334,874)
Net change in income taxes	223,137	67,815	(772,079)
Net increase (decrease)	(312,394)	46,362	1,219,260
Standardized measure - end of period	$     1,958,238	$     2,270,632	$       2,224,270

48

       Supplemental Information (unaudited)

       Page Six

Quarterly Financial Data (unaudited)

2004

	First	Second	Third	Fourth
	Quarter	Quarter	Quarter	Quarter
	(restated)	(restated)		(restated)
Operating Revenues	$  1,386,281	$  1,134,910	$    223,006	$     1,754,473
Net Income (Loss)	$     255,258	$    (940,409)	$   (479,104)	$          (6,750)
Net Income (Loss) per Common Share	$           0.01	$         (0.05)	$        (0.02)	$            (0.00)

(restated) 2003

	First	Second	Third	Fourth
	Quarter	Quarter	Quarter	Quarter
			(restated)	(restated)
Operating Revenues	$       276,780	$   1,190,371	$   3,137,062	$    1,860,032
Net Income (Loss)	$     (421,407)	$    (152,183)	$   172,570	$       896,129
Net Income (Loss) per Common Share	$           (0.02)	$          (0.01)	$            0.01	$             0.04

2002

	First	Second	Third	Fourth
	Quarter	Quarter	Quarter	Quarter
Operating Revenues	$       182,734	$      857,241	$   3,923,875	$       1,321,058
Net Income (Loss)	$     (264,117)	$    (360,283)	$   1,071,553	$          321,977
Net Income (Loss) per Common Share	$           (0.01)	$          (0.02)	$            0.05	$             0.02

49

Item 9A.    Controls and Procedures

Evaluation of Disclosure Controls

The Company conducted an evaluation, under the supervision and with the participation of the Company's principal executive officer and principal financial officer, of the effectiveness of the design and operation of the Company's disclosure controls and procedures (as defined in the Securities Exchange Act of 1934 Rules 13a-15(e) and 15d-15(e)) as of December 31, 2004.

Based upon that evaluation, the Chief Executive Officer and Chief Financial Officer concluded that the Company's disclosure controls and procedures as of the end of the period covered by this report were not effective as a result of material weaknesses in internal controls as of December 31, 2004 as discussed below.

Management Report on Internal Control

Management is responsible for establishing and maintaining adequate internal control over financial reporting of the Company. Internal control over financial reporting is a process designed to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with accounting principles generally accepted in the United States of America.

The Company's internal control over financial reporting includes those policies and procedures that (i) pertain to the maintenance of records that, in reasonable detail, accurately and fairly reflect the transactions and dispositions of the assets of the company; (ii) provide reasonable assurance that transactions are recorded as necessary to permit preparation of financial statements in accordance with accounting principles generally accepted in the United States of America, and that receipts and expenditures of the Company are being made only in accordance with authorizations of management and directors of the Company; and (iii) provide reasonable assurance regarding prevention or timely detection of unauthorized acquisition, use or disposition of the Company's assets that could have a material effect on the financial statements.

Management conducted an evaluation of the effectiveness of internal control over financial reporting based on the framework in Internal Control-Integrated Framework issued by the Committee of Sponsoring Organizations of the Treadway Commission. Based on this evaluation, management concluded that the Company's internal control over financial reporting was not effective as of December 31, 2004. Management identified internal control deficiencies, which, in management's judgment, represented material weaknesses in internal control over financial reporting. The control deficiencies generally related to:

(i)	The following company-level controls:
-	Insufficient personnel with appropriate qualifications and training in key accounting roles, and ineffective assignment of authority and responsibility resulting from the limited accounting personnel;
-	No consistent risk assessment process;
-	Inadequate controls to monitor the results of operations and other control activities;
-	Inconsistent or inadequate policies and procedures which affect the information and communication controls throughout the company;
-	Incompatibility of duties surrounding financial reporting and control activities;
-	Inadequate controls over the period-end financial reporting process including the lack of procedures used for calculating significant estimates, performing consolidation entries, and considering the possibility of unrecorded transactions and disclosures.
(ii)	The discovery of a material error, which resulted in a restatement of previously issued financial statements.

A material weakness in internal controls is a significant deficiency, or combination of significant deficiencies, that results in more than a remote likelihood that a material misstatement of the financial statements would not be prevented or detected on a timely basis by the Company.

Management will continue to evaluate the effectiveness of Tri Valley Corporation's disclosure controls and procedures and internal controls over financial reporting on an ongoing basis and will take further action and implement improvements as necessary.

50

Management's assessment of the effectiveness of the Company's internal control over financial reporting as of December 31, 2004 has been audited by Brown Armstrong Paulden McCown Starbuck & Keeter Accountancy Corporation, an independent registered public accounting firm, as stated in their report, which is included herein.

 There has been no change in the Company's internal control over financial reporting that occurred during the fourth fiscal quarter of 2004 that has materially affected, or is reasonably likely to materially affect, the Company's internal control over financial reporting.

Report of Independent Registered Public Accounting Firm

To the Board of Directors and

Stockholders of Tri-Valley Corporation

Bakersfield, CA

We have audited management's assessment, included in the accompanying Management's Report on Internal Control over Financial Reporting, that Tri-Valley Corporation did not maintain effective internal control over financial reporting as of December 31, 2004, because of the material weaknesses identified in management's assessment based on criteria established in Internal Control-Integrated Framework issued by the Committee of Sponsoring Organization of the Treadway Commission (COSO). Tri-Valley Corporation's management is responsible for maintaining effective internal control over financial reporting and for its assessment of the effectiveness of internal control over financial reporting. Our responsibility is to express an opinion on management's assessment and an opinion on the effectiveness of the company's internal control over financial reporting based on our audit.

We conducted our audit in accordance with the standards of the Public Company Accounting Oversight Board (United States). Those standards require that we plan and perform the audit to obtain reasonable assurance about whether effective internal control over financial reporting was maintained in all material respects. Our audit included obtaining an understanding of internal control over financial reporting, evaluating management's assessment, testing and evaluating the design and operating effectiveness of internal control, and performing such other procedures as we considered necessary in the circumstances. We believe that our audit provides a reasonable basis for our opinion.

A company's internal control over financial reporting is a process designed to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles. A company's internal control over financial reporting includes those policies and procedures that (1) pertain to the maintenance of records that, in reasonable detail, accurately and fairly reflect the transactions and dispositions of the assets of the company; (2) provide reasonable assurance that transactions are recorded as necessary to permit preparation of financial statements in accordance with generally accepted accounting principles, and that receipts and expenditures of the company are being made only in accordance with authorizations of management and directors of the company; and (3) provide reasonable assurance regarding prevention or timely detection of unauthorized acquisition, use, or disposition of the company's assets that could have a material effect on the financial statements.

Because of its inherent limitations, internal control over financial reporting may not prevent or detect misstatements. Also, projections of any evaluation of effectiveness to future periods are subject to the risk that controls may become inadequate because of changes in conditions, or that the degree of compliance with the policies or procedures may deteriorate.

A material weakness is a control deficiency, or combination of control deficiencies, that results in more than a remote likelihood that a material misstatement of the annual or interim financial statements will not be prevented or detected. The following material weaknesses have been identified and included in management's assessment. Insufficient personnel with appropriate qualifications and training in key accounting roles, and ineffective assignment of authority and responsibility resulting from the limited accounting personnel; no consistent risk assessment process; inadequate controls to monitor the results of operations and other control activities; inconsistent or inadequate policies and procedures which affect the information and communication controls throughout the

51

company; incompatibility of duties surrounding financial reporting and control activities; controls over the period-end financial reporting process including the procedures used for calculating significant estimates, performing consolidation entries, and considering the ;possibility of unrecorded transactions and disclosures; and a material financial statement error which resulted in a restatement of previously issued financial statements These material weaknesses were considered in determining the nature, timing, and extent of audit tests applied in our audit of the 2004 financial statements, and this report does not affect our report dated March 29, 2005 on those financial statements.

In our opinion, management's assessment that Tri-Valley Corporation did not maintain effective internal control over financial reporting as of December 31, 2004, is fairly stated, in all material respects, based on criteria established in Internal Control-Integrated Framework issued by the Committee of Sponsoring Organizations of the Treadway Commission (COSO). Also, in our opinion, because of the effect of the material weaknesses described above on the achievement of the objectives of the control criteria, Tri-Valley Corporation has not maintained effective internal control over financial reporting as of December 31, 2004, based on criteria established in Internal Control-Integrated Framework issued by the Committee of Sponsoring Organizations of the Treadway Commission (COSO).

BROWN ARMSTRONG PAULDEN

McCOWN STARBUCK & KEETER

ACCOUNTANCY CORPORATION

Bakersfield, CA

March 29, 2005

52

PART III

ITEM 10 Directors and Executive Officers of the Registrant

All directors of the Company serve one year terms from the time of their election to the time their successor is elected and qualified. The following information is furnished with respect to each director and executive officer:

		Year First
		Became Director or	Position With
Name of Director	Age	Executive Officer	Company
F. Lynn Blystone	69	1974	President, CEO, Director, TVC
			CEO and Director, TVOG
			President, CEO, Director, TVPC
Dennis P. Lockhart(1)	57	1982	Director
Milton J. Carlson(1)	74	1985	Director
Harold J. Noyes(2)	56	2002	Director
Loren J. Miller(1)	59	1992	Director
C. Chase Hoffman(2)	81	2000	Director
Thomas J. Cunningham	62	1997	Treasurer, Chief Financial Officer and
			Secretary, TVC, TVOG, and TVPC
Joseph R. Kandle	62	1999	President, TVOG

(1)- Member of Audit Committee

(2) Member of Compensation Committee

F. Lynn Blystone - 69 President and Chief Executive Officer of Tri-Valley Corporation and Tri-Valley Power Corporation, CEO of Tri-Valley Oil & Gas Company and Select Resources Corporation, which are three wholly owned subsidiaries of Tri-Valley Corporation, Bakersfield, California, Chairman of Alpha Minerals & Chemicals. LLC 1974

Mr. Blystone became president of Tri-Valley Corporation in October, 1981, and was nominally vice president from July to October, 1981. His background includes institution management, venture capital and various management functions for a mainline pipeline contractor including the Trans Alaska Pipeline Project. He has founded, run and sold companies in several fields including Learjet charter, commercial construction, municipal finance and land development. He is also president of a family corporation, Bandera Land Company, Inc., with real estate interests in Kern, Riverside and Orange Counties California. A graduate of Whittler College, California, he did graduate work at George Williams College, Illinois in organization management. He gives full time to Tri-Valley.

53

Dennis P. Lockhart - 57 Director 1982

Mr. Lockhart is a professor at Georgetown University. He was previously Managing Partner of Zephyr Management L.P., an international private equity investment fund sponsor/manager headquartered in New York. He remains a partner in this firm. He is also (non-executive) Chairman of the Small Enterprise Assistance Funds (SEAF),a not-for-profit operator of emerging markets venture capital funds focused on the small and mid-sized company sector. He is a director of CapitalSource Inc. (NYSE) and SMELoan Asia/Maveo Systems (private, Hong Kong based). In 2002 and 2003 he was an Adjunct Professor at the Johns Hopkins University School of Advanced International Studies. From 1988 to 2001, he was President of Heller International Group Inc., a non-bank corporate and commercial finance company operating in 20 countries, and a director of the group's parent, Heller Financial Inc. From 1971 to 1988 he held a variety of international and domestic positions at Citibank/Citicorp (now Citigroup) including assi gnments in Lebanon, Saudi Arabia, Greece, Iran and the bank's Latin American group in New York. In 1999, he was Chairman of the Advisory Committee of the U.S. Export Import Bank. He is a graduate of Stanford University and The John Hopkins University School of Advanced International Studies. He also attended the Senior Executive Program at the Sloan School of Management, Massachusetts Institute of Technology. Mr. Lockhart is an independent member of our Board of Directors.

Milton J. Carlson - 74 Director 1985

Since 1989, Mr. Carlson has been a principal in Earthsong Corporation, which, in part, consults on environmental matters and performs environmental audits for government agencies and public and private concerns. Mr. Carlson attended the University of Colorado at Boulder and the University of Denver. Mr. Carlson is an independent member of our Board of Directors.

Loren J. Miller, CPA - 59 Director 1992

Mr. Miller has served in a treasury and other senior financial capacities at the Jankovich Company since 1994. Prior to that he served successively as vice president and chief financial officer of Hershey Oil Corporation from 1987 to 1990 and Mock Resources from 1991 to 1992. Prior to that he was vice president and general manager of Tosco Production Finance Corporation from 1975 to 1986 and was a senior auditor the accounting firm of Touche Ross & Company from 1968 to 1973. He is experienced in exploration, production, product trading, refining and distribution as well as corporate finance. He holds a B.S. in accounting and a M.B.A. in finance from the University of Southern California. Mr. Miller is an independent member of our Board of Directors.

Harold J. Noyes - 56 Director, President of Select Resources Corporation, a wholly owned subsidiary of Tri-Valley Corporation, Director of Tri-Valley Corporation, Director of Alpha Minerals & Chemicals, LLC 2002

Since January 2005 he has been president of Select Resources Corporation, a newly formed wholly owned subsidiary of Tri-Valley Corporation. Prior to that he was the president of H.J. Noyes and Associates, Inc., a firm that provides consulting and business development services to the minerals industry. Dr. Noyes is currently a senior program manager with Pacific Northwest National Laboratory. He served October 2001 through October 2002 as vice president, marketing and business development for Blake Street Investments, Inc., a money management and investment advisory firm. From 1997 to 2000 he was president of North Star Exploration, Inc. He was manager, resource development for Doyon Limited from 1983 to 1997. Dr. Noyes graduated from the University of Minnesota Magna Cum Laude in geology and took his Ph.D. in geology and geochemistry at the Massachusetts Institute of Technology. Later he earned a Masters in Business Administration at the University of Chicago. In 2004, Mr. Noyes was an indepe ndent member of our board of directors.

54

C. Chase Hoffman - 81 Director 2000

Since 1965 Mr. Hoffman has owned and operated a milk cow dairy and farmed 4,000 acres of land. Additionally, he has been a commercial and residential land developer in California and Hawaii since 1978. From 1973 to 1978 he was a senior vice president and general manager for Knudsen for the State of California. Mr. Hoffman also sits as a director for two companies whose shares are listed on the Canadian Venture Exchange: Seine River Resources, Inc., Vancouver, British Columbia, with California gold operations and Guatemala oil properties, and International Powerhouse Energy Corporation, a British Columbia, Canada, hydroelectric project. He is a graduate of Stanford University with a degree in Economics and Business Administration from Graduate School of Business. Mr. Hoffman is an independent member of our Board of Directors.

  Thomas J. Cunningham - 62 Secretary, Treasurer and Chief Financial Officer of Tri-Valley Corporation, and its wholly owned subsidiaries, Tri-Valley Oil & Gas Company, Tri-Valley Power Corporation and Select Resources Corporation, Bakersfield, California, CFO and Director of Alpha Minerals & Chemicals 1997

Named as Tri-Valley Corporation's treasurer and chief financial officer in February 1997, and as corporate secretary on December 1998. From 1987 to 1997 he was a self employed management consultant in finance, marketing and human resources. Prior to that he was executive vice president, chief financial officer and director for Star Resources from 1977 to 1987. He was the controller for Tucker Drilling Company from 1974 to 1977. He has over 25 years experience in corporate finance, Securities Exchange Commission public company reporting, shareholder relations and employee benefits. He received his education from Angelo State University, Texas.

Joseph R. Kandle - 62 President and Chief Operating Officer Tri-Valley Oil & Gas Company, wholly owned subsidiary of Tri-Valley Corporation Bakersfield, California 1998

Mr. Kandle was named as president of Tri-Valley Oil & Gas Co. February 1999 after joining the Company June 1998 as vice president - engineering. From 1995 to 1998 he was employed as a petroleum engineer for R & R Resources, self-employed as a consulting petroleum engineer from 1994 to 1995. He was vice president - engineering for Atlantic Oil Company from 1983 to 1994. From 1981 to 1983 he was vice president for Star Resources. He was vice president and chief engineer for Great Basins Petroleum from 1973 to 1981. He began his career with Mobil Oil (from 1965 to 1973) after graduating from the Montana School of Mines in 1965.

Audit Committee

The independent directors that serve on the audit committee are Loren J. Miller, Dennis P. Lockhart and Milton J. Carlson. The board of directors has determined that Loren J. Miller is considered to be the audit committee financial expert. Please see his biography above.

55

Compliance with Section 16(a) of the Exchange Act

Section 16(a) of the Securities Exchange Act of 1934 and Securities and Exchange Commission regulations require that the Company's directors, certain officers, and greater than 10 percent shareholders file reports of ownership and changes in ownership with the SEC and must furnish the Company with copies of all such reports they file. Based solely on the information furnished to the Company, we believe that no person failed to file required Section 16(a) reports on a timely basis during or in respect of 2001.

Code of Ethics

We have adopted a code of ethics that applies to our chief executive officer and chief financial officer. A copy of the code of ethics is attached to this 10-K Report as and exhibit.

ITEM 11 Executive Compensation

The following table summarizes the compensation of the chairman of the board and the president of the Company and its subsidiaries, F. Lynn Blystone (the "Named Officer"), for the fiscal year ended December 31, 2004, 2003, and 2002.

Independent directors C. Chase Hoffman and Harold J. Noyes served as the compensation committee for fiscal year 2004.

					Long Term
					Compensation
		Annual Compensation			Awards
(a)	(b)		( c )	(d)		(e)
				Other		Securities
Name	Period Covered		Salary	Compensation		Underlying Options
F. Lynn	FYE 12/31/04		$108,900	$25,000
Blystone, CEO	FYE 12/31/03		$ 99,000	$50,000
	FYE 12/31/02		$ 99,000	$50,000

Employment Agreement with Our President

We have an employment agreement with F. Lynn Blystone, our President and Chief Executive Officer, which ended in August 2002, and was automatically renewable for three one-year periods after 2002, unless terminated by giving 90 days written notice. The base salary amount is $99,000 per year plus 5,000 shares of our common stock at the end of each year of service. Mr. Blystone is also entitled to a bonus (not to exceed $25,000) equal to 10% of net operating cash flow before taxes, including interest income and excluding debt service. Mr. Blystone is also entitled to a bonus of 4% of the company's annual net after-tax income. The total of the bonuses from cash flow and net income may not exceed $50,000 per year.The employment agreement also provides a severance payment to Mr. Blystone if he is terminated within 12 months after a sale of control of Tri-Valley. The severance payment equals $150,000. For purposes of the severance provision, a sale of control is deemed to be the sale of ownership of 30% of the outstanding stock of Tri-Valley or the acquisition by one person of enough stock to appoint a majority of the board of directors of the company.

We carry key man life insurance of $500,000 on Mr. Blystone's life.

Compensation Committee Report

The Compensation Committee Report will be filed with the proxy statement for the annual shareholders meeting.

56

The Compensation Committee of the Board of Directors and the Chairman conducted a compensation survey during 2004 to assess the appropriateness of the compensation of Tri-Valley's senior management team. The survey included review of contemporary publicly available literature and informal discussions with representatives of other comparable companies. The literature survey included review of published summaries of compensation for executives and senior professionals in the oil and gas industry and for executives in companies of similar market capitalization. Informal discussions with industry representatives were conducted among peers in the oil and gas and minerals industries. The survey indicated that compensation of Tri-Valley's executives was substantially below industry standards. This situation reflected Tri-Valley's conservative history of keeping salaries low during previous downturns in the Company's core business. However, considering the extremely competitive nature of the oil and gas industry, the importance of Tri-Valley's management team, and the anticipated future development opportunities in Tri-Valley's business lines, it was determined appropriate to provide salary increases to Tri-Valley's executives. The salary adjustments provide a compensation package that is more consistent with similar positions in the industry.

C. Chase Hoffman

Harold J. Noyes

Members of the Compensation Committee

Aggregated 2004 Option Exercises and Year-End Values

The following table summarizes the number and value of all unexercised stock options held by the Named Officer and the Directors at the end of 2004.

( a )	(b)	(c)	(d)	(e)
			Number of Securities	Value of Unexercised In-
			Underlying Unexercised	The-Money Options/SARs
			Options/SARs at FY-End (#)	at FY-End ($)*
	Shares Acquired On Exercise (#)
Name		ValueRealized ($)	Exercisable/Unexercisable	Exercisable/Unexercisable
F. Lynn Blystone	17,000	$41,970	857,600/0	$9,414,148/0
C. Chase Hoffman	200,000	$1,049,000
Loren J.Miller	220,000	$1,324,500	50,000	$490,000

         *Based on a fair market value of $12.23 per share, which was the closing price of the Company's Common Stock on the American Stock Exchange on December 31, 2004.

No additional stock options were granted in 2004.

Compensation of Directors

The Company compensates non-employee directors for their service on the board of directors.

The following table sets forth information regarding the cash compensation paid to outside directors in 2004.

(a)	(b)	(c)
Name	Fees	Restricted Shares
Harry J. Noyes	$5,650	4,000
Milton Carlson	$6,600	4,000

57

(a)	(b)	(c)
Name	Fees	Restricted Shares
Dennis P. Lockhart	$6,350	4,000
Loren J. Miller	$7,000	4,000
C. Chase Hoffman	$6,050	4,000

Performance Graph

The following stock price performance graph is included in accordance with the SEC's executive compensation disclosure rules and is intended to allow stockholders to review our executive compensation policies in light of corresponding stockholder returns, expressed in terms of the appreciation of our common stock relative to two broad-based stock performance indices. The information is included for historical comparative purposes only and should not be considered indicative of future stock performance. The graph compares the yearly percentage change in the cumulative total stockholder return on our common stock with the cumulative total return of Royale Energy, Inc., Parallel Petroleum Corporation and Equity Oil Company from December 31, 2000 through December 31,

2004. On July 20, 2004, Whiting Petroleum Corporation and Equity Oil Company completed their merger, resulting in Equity becoming a wholly-owned subsidiary of Whiting.

Total returns assume $100 invested on December 31, 2000 in shares of Tri-Valley Corporation, Royale Energy Inc., Parallel Petroleum Corporation, and Equity Oil Company, assuming reinvestment of dividends for each measurement period.

Total Return Analysis
	12/31/2000	12/31/2001	12/31/2002	12/31/2003	12/31/2004
Tri-Valley Corp	$          100.00	$             98.77	$            86.42	$           271.60	$          754.94
Royale Energy, Inc.	$          100.00	$           101.18	$            92.34	$           241.06	$          141.45
Parallel Petroleum Corp.	$          100.00	$             83.46	$            71.92	$           114.17	$          141.47
Equity Oil Co.	$          100.00	$             51.43	$            57.14	$           112.29	$          864.29

ITEM 12 Security Ownership of Certain Beneficial Owners and Management

As of December 31, 2004, there were 21,836,052 shares of the Company's common stock outstanding. The following persons were known by the Company to be the beneficial owners of more than 5% of such outstanding common stock:

	Number of	Percent of
Name and Address	Shares	Total
F. Lynn Blystone P.O. Box 1105 Bakersfield, CA 93302	1,295,603(1)	5.7%

Includes 857,600 shares of stock Mr. Blystone has the right to acquire upon the exercise of options.

The following table sets forth the beneficial ownership of the Company's common stock as of December 31, 2004 by each director, by each of the executive officers named in Item 11, and by the executive officer named in Item 10 and directors as a group:

58

	Number of	Percent of
Directors	Shares(1)	Total(2)
F. Lynn Blystone	1,295,603	5.7%
Dennis P. Lockhart	345,191	1.6%
Milton J. Carlson	349,000	1.6%
Loren J. Miller	309,300	1.4%
Harold J. Noyes	114,000	0.5%
C. Chase Hoffman	271,500	1.2%
Total group (all directors and
Executive officers - 6 persons)	2,684,594	12.0%

(1)	Includes shares which the listed shareholder has the right to acquire from options as follows: Dennis P. Lockhart 270,000; Milton J. Carlson 268,000; Loren J. Miller 50,000, Harold J. Noyes 100,000; F. Lynn Blystone 857,600.
(2)	Based on total outstanding shares of 21,836,052 as of December 31, 2004. The persons named herein have sole voting and investment power with respect to all shares of common stock shown as beneficially owned by them, subject to community property laws where applicable.

ITEM 14 Principal Accountant Fees and Services

	2004	2003
Audit Fees	$71,955	$51,855
Audit-Related Fees	10,464	6,474
Tax Fees	11,725	20,096
All Other Fees	17,882	5,375
Tri-Valley's audit committee charter provides that the audit committee is responsible for determining the independence of the company's outside auditor and must approve in advance, all audit and non-audit services provided by the outside auditor.All services listed as "Other Fees" in the foregoing table, consisting of advice on compliance with SEC reporting requirements and review of management's report on internal control over financial reporting were approved by the audit committee in advance.
ITEM 15 Exhibits and Financial Statement Schedules

Exhibit
Number	Description of Exhibit
3.1	Amended and Restated Certificate of Incorporation, incorporated by reference to Exhibit A of the Company's 2000 Proxy Statement and Definitive Schedule 14A, filed with the SEC on July 26, 2000.
3.2	Amended and Restated Bylaws, incorporated by reference to Exhibit 3.3 of the Company's Form 10-KSB for the year ended December 31, 1999, filed with the SEC on March 24, 2000.

59

4.1	Rights Agreement, incorporated by reference to Exhibit 99.1 of the Company's Form 10-KSB for the year ended December 31, 1999, filed with the SEC on March 24, 2000.
10.1	Employment Agreement with F. Lynn Blystone, incorporated by reference to Exhibit 10.1 of the Company's Form 10-KSB/A, Amendment No. 3 to Form 10-KSB for the year ended December 31, 2000, filed with the SEC on December 14, 2001.
10.2	Tri-Valley Corporation 1999 Stock Option Plan, as amended, incorporated by reference to Exhibit B of the Company's 1999 Proxy Statement and Definitive Schedule 14A, filed with the SEC on October 1, 1999.
14.1	Code of Business Conduct & Ethics, incorporated by reference to Exhibit 14.1 of the Company's Form 10-K for the year ended December 31, 2004, filed with the SEC on March 31, 2005
21.1	Subsidiaries of the Registrant, incorporated by reference to Exhibit 21.1 of the Company's Form 10-K for the year ended December 31, 2004, filed with the SEC on March 31, 2005
31.1	Certification Pursuant to Rule 13a-14(a) / 15d-14(a), filed herewith
31.2	Certification Pursuant to Rule 13a-14(a) / 15d-14(a), filed herewith
32.1	Certification Pursuant to 18 U.S.C. Section 1350, filed herewith
32.2	Certification Pursuant to 18 U.S.C. Section 1350, filed herewith

SIGNATURES

Pursuant to the requirements of Section 13 or 15(d) 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.

September 20, 2005	/s/ F. Lynn Blystone
	F. Lynn Blystone
	President, Chief Executive Officer and Director
September 20, 2005	/s/ Thomas J. Cunningham
	Thomas J. Cunningham
	Secretary, Treasurer, Chief Financial Officer

60