UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D. C. 20549

FORM 10-K

x Annual Report Pursuant to Section 13 or 15(d) of the Securities Exchange Act of 1934

For the fiscal year ended December 31, 2012

 ̈ Transition Report Pursuant to Section 13 or 15(d) of the Securities Exchange Act of 1934

For the transition period from ______ to _______

Commission File Number 001-32989

PYRAMID OIL COMPANY

(Exact Name of registrant as specified in its charter)

CALIFORNIA 94-0787340

(State of other jurisdiction of

incorporation or organization)

(I.R.S. Employer

Identification No.)

2008 – 21

st

. Street. P.O. Box 832, Bakersfield, California 93302

(Address of principal executive offices) (Zip Code)

Registrant's telephone number: (661) 325-1000

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

Common Stock NYSE MKT

(Title of each class) (Name of each exchange on which registered)

Securities registered under Section 12 (g) of the Exchange Act: NONE

Indicate by check mark if the registrant is a well-known seasoned issuer, as defined in Rule 405 of the Securities Act. Yes  ̈ No x

Indicate by check mark if the registrant is not required to file reports pursuant to Section 13 or Section 15(d) of the Exchange Act.

Yes  ̈ No x

Indicate by check mark whether the registrant (1) has filed all reports required to be filed by Section 13 or 15 (d) of the Securities

Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrant was required to file such reports), and (2)

has been subject to such filing requirements for the past 90 days. Yes x No  ̈

Indicate by check mark whether the registrant has submitted electronically and posted on its corporate Website, if any, every

Interactive Data File required to be submitted and posted pursuant to Rule 405 of Regulation S-T during the preceding 12 months (or such

shorter period that the registrant was required to submit and post such files). Yes x No  ̈

Indicate by check mark if disclosure of delinquent filers pursuant to Item 405 of Regulation S-K is not contained herein, and will not

be contained, to the best of 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 a large accelerated filer, an accelerated filer, a non-accelerated filer or a smaller

reporting company. See the definitions of large accelerated filer, accelerated filer and smaller reporting company in Rule 12b-2 of the Exchange

Act.

Large accelerated filer  ̈ Accelerated Filer  ̈

Non-accelerated filer  ̈ Smaller reporting company x

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

The aggregate market value on June 30, 2012, (the last business day of the registrant's most recently completed second fiscal quarter)

of the voting shares held by non-affiliates was approximately $12,972,000 based on the closing sales price of the registrant's Common Stock

on such date.

At March 29, 2013, there were 4,688,085 shares of Common Stock outstanding.
DOCUMENTS INCORPORATED BY REFERENCE

Portions of the registrant's definitive proxy statement for its 2013 Annual Meeting of Shareholders to be filed with the Securities and

Exchange Commission within 120 days after the close of the registrant's fiscal year are incorporated by reference into Part III.
PYRAMID OIL COMPANY

2012 FORM 10-K ANNUAL REPORT

Table of Contents

Page

PART I

Item 1. Business 4

Item 1A. Risk Factors 6

Item 1B. Unresolved Staff Comments 11

Item 2. Properties 11

Item 3. Legal Proceedings 16

Item 4. Mine Safety Disclosures 16

PART II

Item 5. Market for Registrant’s Common Equity, Related Stockholder Matters and Issuer Purchases of Equity Securities 16

Item 6. Selected Financial Data 17

Item 7. Management's Discussion and Analysis of Financial Condition and Results of Operations 17

Item 7A. Quantitative and Qualitative Disclosures about Market Risk 25

Item 8. Financial Statements and Supplementary Data 26

Item 9. Changes In and Disagreements with Accountants on Accounting and Financial Disclosure 58

Item 9A. Controls and Procedures 58

Item 9B. Other Information 59

PART III

Item 10. Directors, Executive Officers and Corporate Governance 59

Item 11. Executive Compensation 59

Item 12. Security Ownership of Certain Beneficial Owners and Management and Related Stockholder Matters 59

Item 13. Certain Relationships and Related Transactions, and Director Independence 60

Item 14. Principal Accounting Fees and Services 60

PART IV

Item 15. Exhibits and Financial Statement Schedules 60

2
CAUTIONARY STATEMENT FOR PURPOSES OF THE PRIVATE SECURITIES LITIGATION REFORM ACT OF 1995

AND OTHER FEDERAL SECURITIES LAWS

Pyramid Oil Company is including the following discussion to inform existing and potential security holders generally of some of the

risks and uncertainties that can affect the Company and to take advantage of the "safe harbor" protection for forward-looking statements

afforded under the federal securities laws. Statements made in this Annual Report on Form 10-K may be forward-looking statements. In

addition, from time to time, the Company may otherwise make forward-looking statements to inform existing and potential security holders

about the Company. These statements may include projections and estimates concerning the timing and success of specific projects and the

Company's future (1) income, (2) oil and gas production, (3) oil and gas reserves and reserve replacement and (4) capital spending. Forwardlooking statements are generally accompanied by words such as "estimate," "project," "predict," "believe," "expect," "anticipate," "plan,"

"goal" or other words that convey the uncertainty of future events or outcomes. In addition, except for the historical information contained in

this report, the matters discussed in this report are forward-looking statements. These statements by their nature are subject to certain risks,

uncertainties and assumptions and will be influenced by various factors. Should any of the assumptions underlying a forward-looking

statement prove incorrect, actual results could vary materially.

PART I

Item 1 - Business

General Business Description

Pyramid Oil Company is a California corporation that has been in the oil and gas business continuously, since it was incorporated on

October 9, 1909. Pyramid Oil Company, hereinafter referred to as "Pyramid" or the "Company", is engaged in the business of exploration,

development and production of crude oil and natural gas.

Pyramid acquires interests in land and producing properties through acquisition and lease on which it drills and/or operates crude oil

or natural gas wells in efforts to discover and/or to produce oil and gas. Crude oil and natural gas produced from these properties are sold to

various refineries and pipeline companies. The majority of all oil and gas properties that Pyramid owns and operates, is for its own account.

Pyramid also participates in specific joint ventures with other companies in the development of oil and gas properties. Pyramid’s interests in

these properties will vary depending on the availability of said interests and their locations. Although the Company owns some minor oil and

gas interests in New York, Texas and Wyoming, all of the Company's operations and major revenue producing properties are in California.

The Company's executive offices are located at 2008-21st Street, Bakersfield, California, 93301, telephone (661) 325-1000, facsimile

(661) 325-0100.

Description of Business - Oil and Gas Operations

Exploration and Development.

Pyramid operates in a highly competitive industry wherein many companies, from large multinational companies to small independent

producers, are competing for a finite amount of oil and gas resources. The Company seeks out properties to explore for oil and gas by drilling

and also seeks out producing oil and gas properties that can be purchased and operated. Management believes that under the right economic

conditions, several of the producing properties that the Company owns could have further developmental potential. Certain oil properties

currently owned and operated by the Company may be receptive to enhanced oil recovery procedures under certain economic conditions.

3
Oil and Gas Production Operations.

Pyramid owns and operates 28 oil and gas leases (properties) located within Kern and Santa Barbara Counties in the State of

California. Nine of these properties were not operated during 2012. All of these properties were shut-down before January 1, 2012. No other

properties were shut-down during 2012. Most of these properties are capable of producing oil or natural gas, although not all of these

properties are considered profitable under certain economic conditions. There are no proved reserves attributed to these properties at December

31, 2012. All of the shut-down properties had been written-down in prior periods.

During 2012, the Company operated 17 leases within California; 15 of these leases had total annual gross oil production exceeding

1,000 barrels per lease. Production activities primarily consist of the daily pumping of oil from a well(s) into tanks, maintaining the production

facilities both at the well and tank settings, preparing and shipping the crude oil to buyers. Daily operations differ from one property to

another, depending on the number of wells, the depth of the wells, the gravity of the oil produced and the location of the property. All of

Pyramid's oil production is classified as primary recovery production at this time; although certain properties may be conducive to secondary

recovery operations in the future, depending on the prevailing price of oil.

Primary recovery of oil and gas is by means of natural flow(s) or artificial lift of oil and gas from a single well bore. Natural gas and

petroleum fluids enter the well bore by means of reservoir pressure or gravity flow; fluids and gases are moved to the surface by natural

pressure or by means of artificial lift (pumping). In secondary recovery operations, liquids or gases are injected into the reservoirs for the

purpose of augmenting reservoir energy or increasing reservoir temperatures. Secondary recovery operations, usually, but not always, are

done after the primary-recovery phase has passed.

The Company employs field personnel (i.e., pumpers, rig crews, roustabouts and equipment operators) that perform basic daily

activities associated with producing oil and gas. Daily operations include inspections of surface facilities and equipment, gauging, reporting

and shipping oil, and routine maintenance and repair activities on wells, production facilities and equipment. The Company owns and

maintains various pieces of equipment necessary for employees to perform various repair and maintenance tasks on Company properties. Such

equipment consists of service rigs, mobile pumps, vacuum trucks, hot oil truck, backhoe, trucks and trailers.

Occasionally, the Company drills new wells or redrills existing wells on properties owned by the Company in an attempt to increase

the daily oil and gas production. In the last five years, the Company has utilized the services of outside drilling contractors for drilling new

wells and redrilling existing wells. Maintenance and repairs of existing wells to maintain or increase oil and gas production are carried out by

Company personnel on a continuing basis. Most maintenance and repair work is performed with Company rigs.

Economic factors associated with the price of oil and gas and the productive output of wells determines the number of active wells the

Company operates. Under certain economic conditions, the Company has the potential to operate approximately 122 wells, and of these,

approximately 51 were in operation during 2012. The Company also owns other oil and gas interests outside of California that it does not

operate. These interests are located in Wyoming, Texas and New York.

4
Marketing of Crude Oil and Natural Gas.

The Company sells its crude oil to Phillips 66 and Kern Oil & Refining, accounting for approximately 51% and 47%, respectively, of

the Company’s crude oil and gas sales in 2012. While revenue from these customers is significant, and the loss of any one could have an

adverse effect on the Company, it is management's opinion that the oil and gas it produces could be sold to other crude oil purchasers,

refineries or pipeline companies. Phillips 66 and its predecessors, and Kern Oil have been customers of the Company for over twenty years.

Natural gas is sold to companies in the area of operations. The Company sells its oil pursuant to short-term contracts. Accordingly, the amount

of oil the Company sells is dependent upon market demand. Market demand for Pyramid's production is subject to various influences and can

never be assured, especially in an era of changing prices. The base values for crude oil the Company sells is set by major oil companies in

response to area and market strengths and international influences. Types and qualities of crude oil vary substantially in base values posted by

crude oil buyers in various areas of the country. Pyramid's crude oil sales are not seasonal, but uniform throughout the year.

Competition and Industry Conditions

The profitability of the Company's operations depends primarily on the production of oil and gas in commercially profitable

quantities. Oil and gas properties often fail to provide a return sufficient to repay the substantial sums of money required for their acquisition,

exploration and development. The acquisition, exploration and development of oil and gas properties is a highly competitive business. Many

entities with which the Company competes have significantly greater financial and staff resources. Such competitive disadvantages could

materially and adversely affect the Company's ability to acquire new properties or develop existing properties.

Regulations

The Company's business is affected by numerous governmental laws and regulations, including energy, environmental, conservation,

tax and other laws and regulations relating to the petroleum industry. Changes in any of these laws and regulations could have a material and

adverse effect on the Company's business and financial stability. In view of the many uncertainties with respect to current laws and

regulations, including their applicability to the Company, the Company cannot predict the overall effect of such laws and regulations on future

operations.

Taxation

The operations of the Company, as is the case in the petroleum industry generally, are significantly affected by Federal tax laws.

Federal, as well as state, tax laws have many provisions applicable to corporations which could affect the future tax liability of the Company.

Environmental

The Company's activities are subject to existing federal and state laws and regulations governing environmental quality and pollution

control. These laws may require the acquisition of permits relating to certain ongoing operations, for drilling, emissions, waste water disposal

and other air and water quality controls. In view of the uncertainty and unpredictability of environmental statutes and regulations, the Company

cannot ensure that such laws and regulations will not materially and adversely affect the business of the Company. The Company does not

currently anticipate any material effect on its capital expenditures or earnings as the result of governmental regulations, enacted or proposed,

concerning environmental protection or the discharge of material into the environment. The Company is actively pursuing an ongoing policy of

upgrading and restoring older properties to comply with current and proposed environmental regulations.

5
Commitments and Contingencies

The Company is liable for future dismantlement and abandonment costs associated with its oil and gas properties. These costs include

down-hole plugging and abandonment of wells, future site restoration, post closure and other environmental exit costs. The costs of future

dismantlement and abandonment have been accrued and recorded in the financial statements. See Note 10 of Notes to Financial Statements

included in Item 8 of this Form 10-K.

Other

The Company employed twelve full-time and two part-time people as of December 31, 2012. Three full-time and two part-time

people were office or administrative personnel, and the rest were field personnel. The Company contracts for additional labor services when

needed. The Company is not a party to any union contracts.

The Company had no material research and development costs for the three years ended December 31, 2012.

All of the Company's revenues during 2012 were derived from domestic sources.

The Company does not have any patents or trademarks, and it does not believe that its business or operations are dependent upon

owning any patents or trademarks.

Item 1A - Risk Factors

In addition to other information in this annual report, the following risk factors should be carefully considered in evaluating the

Company's business because such factors may have a significant impact on the Company's business, operating results, liquidity and financial

condition. As a result of the risk factors set forth below, actual results could differ materially from those projected in any forward-looking

statements. Additional risks and uncertainties not presently known to us, or that we currently consider to be immaterial, may also impact the

Company's business, operating results, liquidity and financial condition. If any such risks occur, the Company's business, operating results,

liquidity and financial condition could be materially affected in an adverse manner. Under such circumstances, the trading price of the

Company's securities could decline, and you may lose all or part of your investment in the Company.

Risks Relating to the Company's Business and the Oil and Gas Industry

The company's future performance is dependent upon the company's ability to continue to identify, acquire and develop

additional oil and gas properties, the failure of which could result in under use of capital and losses.

The Company's future performance depends upon the Company's ability to continue to identify, acquire and develop additional oil

and gas reserves that are economically recoverable. The Company's success will depend upon the Company's ability to continue to acquire

working and revenue interests in properties upon which oil and gas reserves are ultimately discovered in commercial quantities, and the

Company's ability to develop additional prospects that contain proven oil and gas reserves to the point of production. The successful

acquisition and development of oil and gas properties requires an assessment of recoverable reserves, future oil and gas prices and operating

costs, potential environmental and other liabilities, and other factors. Such assessments are necessarily inexact and their accuracy inherently

uncertain. In addition, no assurance can be given that the Company's future exploitation and development activities will result in the discovery

of additional reserves.

6
The company has a very small management team and the loss of any member of the company's team may prevent us from

implementing the company's business plan in a timely manner.

The Company currently has two executive officers and a small number of full time employees and consultants upon whom the

Company's success largely depends. We do not maintain key person life insurance policies on the Company's executive officers or

consultants, the loss of whom could seriously harm the Company's business, financial condition and results of operations. In such an event,

we may not be able to recruit personnel to replace the Company's executive officers or consultants in a timely manner, or at all, or on

acceptable terms.

The oil and gas industry is highly competitive, and the company may not have sufficient resources to compete effectively.

The oil and gas industry is highly competitive. The Company competes with oil and natural gas companies and other individual

producers and operators, many of which have substantially greater financial and other resources than the Company. The Company's larger

competitors, by reason of their size and relative financial strength, can more easily access capital markets than the Company can and may enjoy

a competitive advantage in the recruitment of qualified personnel. Competitors may be able to absorb the burden of any changes in laws and

regulations in the jurisdictions in which the Company does business and handle longer periods of reduced prices for oil and gas more easily

than we can. The Company's competitors may be able to pay more for oil and gas leases and properties and may be able to define, evaluate, bid

for and purchase a greater number of leases and properties than the Company can. Further, these companies may enjoy technological

advantages and may be able to implement new technologies more rapidly than the Company can. The Company's ability to acquire additional

properties in the future will depend upon the Company's ability to conduct efficient operations, evaluate and select suitable properties,

implement advanced technologies and consummate transactions in a highly competitive environment.

The company's exploration, development and production activities are subject to certain environmental regulations which

may affect the company's costs of operations.

In general, the Company's exploration and production activities are subject to certain federal, state and local laws and regulations

relating to environmental quality and pollution control. Such laws and regulations increase the costs of these activities and may prevent or

delay the commencement or continuance of a given operation. Specifically, the Company is subject to legislation regarding emissions into the

environment, water discharges and storage and disposition of hazardous wastes. However, such laws and regulations are frequently changed

and any such changes may have material adverse effects on the Company's activities. The Company is unable to predict the ultimate cost of

compliance with such laws and regulations. Generally, environmental requirements do not appear to affect the Company any differently or to

any greater or lesser extent than other companies in the industry. To date the Company has not been required to spend any material amounts on

compliance with environmental regulations. However, the Company may be required to do so in future and this may affect the Company's

ability to expand or maintain the Company's operations.

7
Any change to government regulation/administrative practices may have a negative impact on the company's ability to

operate and the company's profitability.

The business of oil and gas exploration and development is subject to substantial regulation under federal, state, local and foreign

laws relating to the exploration for, and the development, upgrading, marketing, pricing, taxation, and transportation of oil and gas and related

products and other matters. Amendments to current laws and regulations governing operations and activities of oil and gas exploration and

development operations could have a material adverse impact on the Company's business. In addition, there can be no assurance that income

tax laws, royalty regulations and government incentive programs related to the Company's oil and gas properties and the oil and gas industry

generally, will not be changed in a manner which may adversely affect the Company's progress and cause delays, inability to explore and

develop or abandonment of these interests.

Permits, leases, licenses, and approvals are required from a variety of regulatory authorities at various stages of exploration and

development. There can be no assurance that the various government permits, leases, licenses and approvals sought will be granted in respect

of the Company's activities or, if granted, will not be cancelled or will be renewed upon expiry. There is no assurance that such permits, leases,

licenses, and approvals will not contain terms and provisions which may adversely affect the Company's exploration and development

activities.

The company is required to replace, maintain or expand the company's oil and gas reserves in order to prevent the

company's future reserves and production from declining, which would adversely affect future cash flows and income.

In general, production from oil and gas properties declines over time as reserves are depleted, with the rate of decline depending on

reservoir characteristics. The Company's future oil and gas production is highly dependent upon the Company's ability to economically find,

develop, acquire and maintain reserves in commercial quantities.

To the extent cash flow from operations is reduced, either by a decrease in prevailing prices for oil and gas or an increase in finding

and development costs, and external sources of capital become limited or unavailable, the Company's ability to make the necessary capital

investment to maintain or expand the Company's asset base of oil and gas reserves would be impaired. Even with sufficient available capital,

the Company's future exploration and development activities may not result in additional proved reserves, and we might not be able to drill

productive wells at acceptable costs.

The oil and gas exploration and production industry is historically a cyclical industry and market fluctuations in the prices

of oil and gas could adversely affect the company's business.

Prices for oil and gas tend to fluctuate significantly in response to factors beyond the Company's control. These factors include:

- weather conditions in the United States and where the Company's property interests are located;

- economic conditions, including demand for petroleum-based products, in the United States and the rest of the world;

- actions by OPEC, the Organization of Petroleum Exporting Countries; political instability in the Middle East and other major

oil and gas producing regions;

- governmental regulations;

- domestic tax policy;

- the price of foreign imports of oil and gas;

8
- the cost of exploring for, producing and delivering oil and gas;

- the discovery rate of new oil and gas reserves;

- the rate of decline of existing and new oil and gas reserves;

- available pipeline and other oil and gas transportation capacity;

- the ability of oil and gas companies to raise capital;

- the overall supply and demand for oil and gas; and

- the availability of alternate fuel sources.

Changes in commodity prices may significantly affect the Company's capital resources, liquidity and expected operating results. Price

changes will directly affect revenues and can indirectly impact expected production by changing the amount of funds available to reinvest in

exploration and development activities. Reductions in oil and gas prices not only reduce revenues and profits, but could also reduce the

quantities of reserves that are commercially recoverable. Significant declines in prices could result in non-cash charges to earnings due to

impairment.

Changes in commodity prices may also significantly affect the Company's ability to estimate the value of producing properties for

acquisition and divestiture and often cause disruption in the market for oil and gas producing properties, as buyers and sellers have difficulty

agreeing on the value of the properties. Price volatility also makes it difficult to budget for and project the return on acquisitions and the

development and exploitation of projects. We expect that commodity prices will continue to fluctuate significantly in the future.

Exploratory and developmental drilling and production operations involves many risks that are outside the company's

control and which may result in a material adverse effect on the company's business, financial condition or results of operations.

The business of exploring for, developing and producing oil and gas involves a substantial risk of investment loss. Drilling and

operating oil and gas wells involves the risk that the wells may be unproductive or that, although productive, the wells may not produce oil or

gas in economic quantities. Other hazards, such as unusual or unexpected geological formations, pressures, fires, blowouts, power outages,

gas leakage, loss of circulation of drilling fluids or other conditions may substantially delay or prevent completion of any well. Adverse

weather conditions can also hinder drilling operations. A productive well may become uneconomic if water or other deleterious substances are

encountered that impair or prevent the production of oil or gas from the well. In addition, production from any well may be unmarketable if it

is impregnated with water or other deleterious substances. There can be no assurance that oil and gas will be economically produced from all

properties in which the Company has interests.

At times the company participates in joint ventures wherein the company is dependent upon the efforts of various third

parties that the company does not control and, as a result, the company may not be able to control the timing of development

efforts, associated costs, or the rate of production of reserves (if any).

The success of the Company's business interests in certain joint ventures, where the Company owns less than a majority interest

depends upon the efforts of various third parties that the Company does not control. As a result, the Company may have limited ability to

exercise influence over certain joint venture decisions, operations or costs in certain joint venture activities. The Company's dependence on the

operator and, where applicable, other working interest owners for these projects and the Company's limited ability to influence operations and

associated costs could prevent the Company from realizing targeted returns on capital in drilling or acquisition activities. The success and

timing of development and exploitation activities on joint venture properties operated by others depend upon a number of factors that will be

largely outside of the Company's control, including:

9
- the timing and amount of capital expenditures;

- the operator's expertise and financial resources;

- approval of other participants in drilling wells;

- selection of technology;

- the rate of production of the reserves; and

- the availability of suitable drilling rigs, drilling equipment, production and transportation infrastructure, and qualified

operating personnel.

The Company relies upon various consultants and service companies to provide us with technical assistance and services. The

Company relies upon the services of geologists, geophysicists, chemists, engineers and other scientists to explore and analyze oil and gas

prospects to determine a method in which the oil and gas prospects may be developed in a cost-effective manner. Although the Company's

management has relationships with a number of third-party service providers, we cannot assure you that we will be able to continue to rely on

such consultants or services in the future.

Risks Related to the Company’s Common Stock

The value of the company's common stock may be adversely affected by market volatility.

The trading price of the Company's common stock fluctuates and may be influenced by many factors, including:

- The Company's operating and financial performance and prospects;

- The depth and liquidity of the market for the Company's common stock;

- Investor perception of the Company and the industry and markets in which the Company operates;

- The Company's inclusion in, or removal from, any equity market indices;

- Changes in earnings estimates or buy/sell recommendations by analysts; and

- General financial, domestic, international, economic and other market conditions.

The company's ability to raise capital in the future may be limited, and the Company's failure to raise capital when needed

could prevent the company from executing its growth strategy.

The timing and amount of the Company's working capital and capital expenditure requirements may vary significantly depending on

many factors, including future oil and gas prices and the amount of the Company's future oil and gas production.

10
If the Company's capital resources are not sufficient to satisfy its liquidity needs, the Company may seek to sell additional equity or

obtain additional debt financing. The sale of additional equity would result in dilution to the Company's shareholders. Additional debt would

result in increased expenses and could result in covenants that would restrict the Company's operations. In addition, the Company may not be

able to obtain additional financing, if required, in amounts on or terms acceptable to the Company, or at all.

The company's by-laws do not contain anti-takeover provisions and thus the company's management and directors may

change if there is a take-over of the company.

We do not currently have a shareholder rights plan or any anti-takeover provisions in the Company's by-laws. Without any antitakeover provisions, there is no deterrent for a take-over of the Company. If there is a take-over of the Company, the Company's management

and directors may change.

Item 1B - Unresolved Staff Comments

None

Item 2 - Properties

(a) Description of Properties

The principal assets of the Company consist of proven and unproven oil and gas properties, oil and gas production related equipment

and developed and undeveloped real estate holdings. The Company's oil and gas properties are located exclusively in the continental United

States, in California, Wyoming, Texas and New York.

The general business description and the description of the Company's oil and natural gas operations are described on page 4 under

Item 1. Business. Information required by Subpart 1200 of Regulation S-K (Disclosure by Registrants Engaged in Oil and Gas Producing

Activities) is also contained in Item 1. and in Item 8. Financial Statements and Supplementary Data, Supplemental Information - Oil and Gas

Producing Activities on pages 51 to 55. The preceding information is incorporated by reference into this Item 2.

Developed oil and gas properties are those on which sufficient wells have been drilled to economically recover the estimated reserves

calculated for the property. Undeveloped properties do not presently have sufficient wells to recover the estimated reserves. The Company did

not have any proved undeveloped reserves at December 31, 2012. The Company had proved undeveloped reserves of 44,700, 77,700, 96,000,

and 9,500 at December 31, 2011, 2010, 2009 and 2008, respectively.

The Company had proved undeveloped reserves of 44,700 barrels of crude oil at December 31, 2011. These reserves were

attributable to two wells that the Company planned to drill in 2012. The Company projected that it would cost approximately $1,281,000 to

drill and complete these wells in 2012. One of these wells the Santa Fe #20 well, a development well, was drilled and completed in the first

quarter of 2012. This well is currently not producing and a valuation allowance of $207,000 was recorded in the fourth quarter against the

Santa Fe lease. The other well that was projected to be drilled in 2012, the CLI 4-H well, was not drilled in 2012 and the Company currently

does not anticipate drilling this well at any time in future years.

11
The Company had proved undeveloped reserves of 77,700 barrels of crude oil at December 31, 2010. These reserves were

attributable to three wells that the Company planned to drill in 2011. The Company projected that it would cost approximately $1,596,000 to

drill and complete these wells in 2011. One of these wells the Pike 1-H, a horizontal well, was spudded in March of 2011. The Company is

drilling this well in conjunction with a joint-venture partner. The Company is the operator of the joint venture.

The Company had proved undeveloped reserves of 96,000 barrels of crude oil at December 31, 2009. These reserves were

attributable to three wells that the Company planned to drill in 2010. The Company projected that it would cost approximately $1,550,000 to

drill and complete these wells in 2010. Two of these wells were drilled in 2010. The Anderson No. 10 well was drilled in the first quarter of

2010 at a cost of $481,000. This well was completed and placed into production in the first quarter of 2010 and is currently under production.

The second well was drilled in the second quarter of 2010. The CLI No. 4-H, was not completed due to the absence of hydrocarbons and was

abandoned as a dry-hole. The cost to drill this well was $867,000. A valuation allowance of $867,000 was recorded in the first and second

quarter against the costs of this well.

The Company had proved undeveloped reserves of 9,500 barrels of gas (which represents the crude oil equivalent of 57,000 MCF's,

gas production is converted to equivalent barrels at the rate of 6 MCF per barrel, representing the estimated relative energy content of gas to

oil) at December 31, 2008. This represents the reserves attributable to a well that was drilled in 2008 on the properties of the Texas natural gas

joint venture. Additional work costing approximately $86,000 was expended to develop these reserves in 2009. The results of this effort in

2009 did not generate the anticipated results. A valuation allowance has been recorded against the full capitalized costs of this well.

The Company has no material amounts of proved undeveloped reserves that have remained undeveloped for five years or more after

disclosure as proved undeveloped reserves.

(b) Oil and Gas Properties

The Company's estimated future net recoverable oil and gas reserves from proved reserves, both developed and undeveloped

properties were assembled by MHA Petroleum Consultants, LLC, independent petroleum engineers, and are as follows:

Crude Oil Natural Gas

(Bbls) (MCF)

December 31, 2012 482,000 0

2011 546,000 42,000

2010 538,000 44,000

2009 506,000 81,000

2008 471,000 155,000

The Company’s estimated future net recoverable oil and gas reserves, noted in the above table, have not been filed with any other

Federal authority or agency since January 1, 2012.

Using the 12 month average of the first-of-the-month oil and gas prices and 12 month average of lease operating expenses, the

estimated value of future net revenues to be derived from Pyramid's proved developed oil and gas reserves, discounted at 10%, were

$13,712,000 at December 31, 2012, $18,439,000 at December 31, 2011, $13,068,000 at December 31, 2010, $9,158,000 at December 31,

2009, and $4,106,000 at December 31, 2008.

Pyramid participates in the drilling of developmental wells, no single one of which would cause a significant change in the net reserve

figure.

12
In December 2008, the SEC issued its final rule, Modernization of Oil and Gas Reporting, which is effective for reporting 2009

reserve information. In January 2010, the FASB issued its authoritative guidance on extractive activities for oil and gas to align its

requirements with the SEC's final rule. We adopted the guidance as of December 31, 2009 in conjunction with our year-end reserve report as a

change in accounting principle. Under the SEC's final rule, prior period reserves were not restated.

Internal Controls over Reserve Estimation

Our proved reserve information as of December 31, 2012 included in this Annual Report on Form 10-K was estimated by our

independent petroleum consultant, MHA Petroleum Consultants, LLC, in accordance with generally accepted petroleum engineering and

evaluation principles and definitions and guidelines established by the SEC. For the company's estimation procedures, credentials and

statement of independence, see the MHA Petroleum Consultants, LLC, report filed herein on Exhibit 99.1. The technical persons responsible

for preparing the reserves estimates presented herein meet the requirements regarding qualifications, independence, objectivity and

confidentiality set forth in the Standards Pertaining to the Estimating and Auditing of Oil and Gas Reserves Information promulgated by the

Society of Petroleum Engineers. MHA Petroleum Consultants, LLC, and their predecessors have been preparing the Company's reserve

information for over twenty years and thus, are very familiar with the Company's operations and their oil and gas properties.

John H. Alexander, President and Lee Christianson, CFO, provide company data (such as well ownership interests, oil and gas

prices, production volumes and well operating costs) to MHA Petroleum Consultants, LLC, and are the primary Company employees

responsible for reviewing MHA Petroleum Consultants, LLC, use of our data and MHA Petroleum Consultants, LLC, estimation of our

reserves. Mr. Alexander and an employee who is a petroleum engineer provide MHA Petroleum Consultants, LLC, with technical data (such

as well logs, geological information and well histories). Mr. Alexander and Mr. Christianson have been with the Company for over twenty

years. Mr. Alexander has over forty years experience in the oil and gas exploration and production industry.

John Alexander and Lee Christianson review the preliminary MHA Petroleum Consultants, LLC, reserve estimates and the financial

inputs in the estimates. Mr. Christianson, CFO, calculates the disclosed changes in reserve estimates and the disclosed changes in the

Standardized Measure relating to proved oil and gas reserves. Mr. Christianson has over thirty years experience in oil and gas accounting.

Our company codes of business conduct and ethics are general internal controls for preventing and detecting errors or fraud by our

employees responsible for the reserve estimation procedures and disclosure in our filings with the SEC.

13
Pyramid's net oil and gas production after royalty and other working interests for the past five years ending December 31, were as

follows:

2012 2011 2010 2009 2008

Crude oil (Bbls) 45,000 55,000 60,000 57,000 65,000

Natural gas (MCF) 6,000 9,000 9,000 5,000 5,000

Pyramid's average sales prices per barrel or per MCF of crude oil and natural gas, respectively, and production costs per equivalent

barrel (gas production is converted to equivalent barrels at the rate of 6 MCF per barrel, representing the estimated relative energy content of

gas to oil) for the past five years ending December 31, were as follows:

2012 2011 2010 2009 2008

Sales price:

Crude oil $ 106.60 $ 104.78 $ 77.10 $ 57.16 $ 93.47

Natural gas $ 2.76 $ 3.87 $ 4.37 $ 4.02 $ 7.94

Production costs $ 41.00 $ 33.00 $ 26.60 $ 24.20 $ 27.20

The average selling price of the Company’s crude oil at December 31, 2012, was approximately $101.62 per barrel and the average

selling price of the Company’s natural gas at December 31, 2012, was approximately $3.52 per MCF.

As of December 31, 2012, Pyramid had the following gross and net position in wells and proved acres:

WELLS PROVED ACRES

Gross (1) Net (1) Gross (2) Net (2)

Oil 128 127 9,191 1,812

Natural Gas 22 7 12,246 4082

150 134 21,437 5,894

(1) "Gross wells" represent the total number of wells in which the Company has a working interest. "Net wells" represent the number of

gross wells multiplied by the percentage of the working interests therein held by the Company.

(2) "Gross acreage" represents all acres in which the Company has a working interest. "Net acres" represent the aggregate of the working

interests of the Company in the gross acres.

The Company drilled one development well in 2012, the Santa Fe No. 20. This well is currently non-producing. A valuation

allowance of $207,000 was recorded in the fourth quarter against the Santa Fe lease.

The company drilled two wells in 2011, the Pike 1-H well and the Jacoby-Potter Unit #1 well. Both of these wells were drilled

jointly with different partners on each well. Both of these wells were drilled in the first quarter of 2011. The Company is the operator of the

Pike 1-H well. The Company’s share of the costs of drilling the Pike well was $897,000. This well was written down by $673,000 during

2011 because the production from the well was lower than projected. The write-down was based on the Company’s share of projected future

net cash flows for the well. The Jacoby-Potter well was drilled by the joint venture in Texas. The Company participated as one of the nonoperators in the drilling of this well. The Company’s share of the costs for drilling this well were $54,000. This well was abandoned as a dryhole. The Company recorded a valuation allowance of $54,000 during 2011 for this well.

14
The Company drilled two new wells in 2010, the Anderson No.10 well and the CLI No. 4-H. The Anderson No. 10 well was drilled

in the first quarter of 2010 and completed as a producing well. The CLI No. 4-H was drilled in the second quarter of 2010 and was abandoned

as a dry-hole. The Company recorded a valuation allowance of $867,468 during the second quarter of 2010 to offset the costs of drilling and

abandoning this well. The Company also redrilled two existing wells during the fourth quarter of 2010, the Wilson No.3 and the

Alexander/Abadie No. 1. Both of these wells are currently under production. These wells had previously been shut-in for a number of years.

At December 31, 2010, the Company recorded a valuation allowance of $237,647 against the costs of redrilling the Alexander/Abadie No. 1

well. The Company also recorded a valuation allowance of $117,412 at December 31, 2010 for one of its Texas joint venture wells.

The Company drilled one well in 2008 on the Santa Fe lease. This well was completed and placed on production during 2008. After

this well was placed on production, it was determined that it was not economic to produce and the well is currently shut-in. The Company also

participated as a non-operator, along with a group of partners, in the drilling of two natural gas wells in Texas, one each in 2008 and 2009.

The gas well that was drilled in 2008 was placed into production. The gas well that was drilled in 2009 was not placed into production until

the first quarter of 2010.

"Unproven" oil and gas properties are those on which the presence of commercial quantities of reserves of crude oil or natural gas has

not been established.

"Undeveloped" acreage exists on those oil and gas properties where economically recoverable reserves are estimated to exist in proved

reservoirs from wells to be drilled in the future.

As of December 31, 2012, Pyramid held positions in unproven acreage in the following locations:

ACRES

Gross Net

New York

Mount Morris and Livingston Counties 34,800 9,788

Texas

McMullen County 5,700 713

(c) Real Property Owned

Pyramid owned the following real property as of December 31, 2012, all located in California.

County of Kern

Mullaney yard 20 acres

Miller property 112 acres

Ranton property 80 acres

Murphy property 50 acres

City of Bakersfield 3 lots

Located on the three lots of real property in the city of Bakersfield are the Company’s executive offices. This property was acquired

by the Company in 1986. The office building located on this property is a one story structure with approximately 4,200 square feet and is in

good condition.

15
Item 3 - Legal Proceedings

The Company is subject to potential litigation within the normal course of business. The resolution in any reporting period of such

litigation could have a material impact on Pyramid's financial position or results of operations for that period. Pyramid is not party to any

proceedings or actions which management believes might have a material effect upon its financial position or results of operations.

Item 4 - Mine Safety Disclosures

Not applicable.

PART II

Item 5 - Market for Registrant’s Common Equity, Related Stockholder Matters and Issuer Purchases of Equity Securities

The common stock of Pyramid is traded on the NYSE MKT under the symbol "PDO". The following are high and low sales prices

for each quarter of 2012 and 2011, and reflect inter-dealer prices without retail markup, markdown or commission.

High Low

Fiscal Quarter Ending 2012

March 31, $ 6.2300 $ 3.8200

June 30, 5.2000 4.0500

September 30, 4.8500 4.0700

December 31, 4.5600 3.7500

Fiscal Quarter Ending 2011

March 31, 8.4500 5.1700

June 30, 7.0300 4.5100

September 30, 5.3400 3.6000

December 31, 4.5300 3.4100

At December 31, 2012, the Company had 193 shareholders of record, and an unknown number of additional holders whose stock is

held in "street name".

The Company did not repurchase any securities during 2012, or issue any securities during 2012 that were not registered under the

Securities Act of 1933.

The Company did not declare or pay any cash dividends on its common stock during the preceding two fiscal years and does not

anticipate paying any cash dividends in the foreseeable future.

16
Item 6 - Selected Financial Data

The following selected financial data is not necessarily indicative of our future financial position or results of future operations, and

should be read in conjunction with Item 7, Management's Discussion and Analysis of Financial Condition and Results of Operations and the

Financial Statements and Notes thereto included in Item 8, Financial Statements and Supplementary Data of this Annual Report on Form 10-

K.

Years Ended December 31,

(In thousands except per share data)

2012 2011 2010 2009 2008

Statement of Operations Data

Total Revenue $ 4,995 $ 5,690 $ 4,836 $ 3,312 $ 6,611

Income from Operations 975 1,161 53 (537) 1,094

Net Income (Loss) 778 1,095 246 (189) 1,514

Net Income (Loss) per Share Basic and Diluted $ 0.17 $ 0.23 $ 0.05 $ (0.04) $ 0.32

Weighted Average Number of Basic Shares

Outstanding 4,686 4,684 4,678 4,678 4,678

Balance Sheet Data

Cash and Cash Equivalents $ 3,834 $ 2,763 $ 1,536 $ 1,439 $ 1,794

Short-term Investments 2,136 2,128 3,059 3,344 2,789

Total Assets 12,761 11,882 10,630 10,142 10,277

Notes Payable 0 55 40 21 45

Stockholders' Equity 10,658 9,881 8,742 8,373 8,352

Total Liabilities and Stockholders' Equity 12,761 11,882 10,630 10,142 10,277

Per Share Data

Net Book Value per

Common Share $ 2.27 $ 2.11 $ 1.87 $ 1.79 $ 1.79

Common Shares Outstanding 4,688 4,684 4,678 4,678 4,678

Item 7 - Management's Discussion and Analysis of Financial Condition and Results of Operations

Impact of Changing Prices

Average prices increased by approximately sixty cents per equivalent crude oil and gas barrel sold during 2012 as compared with

average prices for 2011. In 2012 there were 244 separate crude oil price changes, as compared with 248 price changes in 2011. The difference

between the highest ($123.80) and lowest ($90.25) posted prices in 2012 was $33.55 per barrel. By comparison, this same differential in 2011

was $36.65 per barrel.

17
Liquidity and Capital Resources

The Company had cash and short-term investments of $5,970,000 at December 31, 2012, for a net increase of $1,079,000, when

compared to December 31, 2011. Short-term investments consist of certificates of deposit having original maturities of three months or more.

During 2012, operating activities generated cash of $2,142,000. During 2012, cash was consumed by capital spending of $979,000 and

principal payments on the Company's long-term debt totaling $55,000. The components of the changes in cash for 2012 are described in the

Statements of Cash Flows included in Item 8 of this Form 10-K. Adequate funds were available to carry out all necessary oil and gas

operations and to maintain its equipment. A $500,000 line of credit, unused at December 31, 2012, also provided additional liquidity during

2012.

The Company believes that its existing current assets and the amount of cash it anticipates it will generate from current operations will

be sufficient to fund the anticipated liquidity and capital resource needs of the Company for the fiscal year ending December 31, 2013. In

addition to its current assets, the Company also has a credit facility for $500,000 available in the event that it needs other resources to fund its

liquidity and capital resource needs. Although the Company may increase its capital expenditures during the current fiscal year to enhance its

current oil production capacities, it does not anticipate that such expenditures would exceed the amount of liquidity currently available to the

Company. The Company's beliefs that its existing assets and the cash expected to be generated from operations will be sufficient during fiscal

year 2013 are based on the following:

As of December 31, 2012, the amount of cash, cash equivalents, and short-term investments was equal to $5,970,000 in the aggregate.

As of December 31, 2012, the Company had approximately $7,072,000 in current assets, and $775,000 of current liabilities.

As of December 31, 2012, the Company had no long-term or current debt.

The Company is not a party to off-balance sheet arrangements and does not engage in trading activities involving non-exchange

traded contracts. In addition, the Company has no financial guarantees, debt or lease agreements or other arrangements that could trigger a

requirement for an early payment or that could change the value of the Company's assets. Management continues to examine various

alternatives for increasing capital resources including, among other things, participation with industry and/or private partners in drilling and

exploration prospects and specific rework of existing properties to enhance production and expansion of its sales of crude oil and natural gas

in California. If necessary, Pyramid could sell certain nonessential assets to raise capital for the benefit of these programs.

The Company drilled one development well during 2012. The Company drilled two joint-venture wells in 2011. The Company

drilled two new wells and re-drilled two existing wells in 2010. The Company participated as a non-operator in the drilling of a natural gas

well in Texas during 2009. The Company drilled two wells in the year ended December 31, 2008.

The Company's proved developed producing crude oil reserves decreased by approximately 19,000 barrels at December 31, 2012.

The decrease in crude oil reserves is due to crude oil production of 45,000 barrels offset by an increase of 26,000 barrels as a result of

revisions of previous estimates.

18
The Company's proved developed producing crude oil reserves increased by approximately 41,600 barrels at December 31, 2011.

The increase in crude oil reserves is due primarily to revisions of previous estimates. The increase in reserves due to revisions of estimates is

due primarily to higher net average crude prices (after production taxes and operating expenses) for 2011. Certain oil and gas properties

recoverable reserves and net revenues increased due to the higher net average prices.

The Company's proved developed producing crude oil reserves increased by approximately 49,500 barrels at December 31, 2010.

The increase in crude oil reserves is due primarily to revisions of previous estimates. The increase in reserves due to revisions of estimates is

due primarily to higher net average crude prices (after production taxes and operating expenses) for 2010. Certain oil and gas properties

recoverable reserves and net revenues increased due to the higher net average prices.

The Company's proved developed producing crude oil reserves decreased by 63,000 barrels at December 31, 2009. The decrease is

due primarily to production of approximately 57,000 barrels of crude oil during 2009. The remaining decline of 6,000 barrels in the reserves is

due to revisions of previous estimates. The Company did not drill any crude oil wells during 2009.

The Company's proved developed producing natural gas reserves decreased by 56,000 MCF's at December 31, 2009. The decrease is

due primarily to revisions of previous estimates. The estimates of gas reserves for the Texas gas prospect decreased by approximately 40,000

MCF's due to unfavorable production results from a gas well that was drilled in 2008 by the Texas joint venture.

The Company's crude oil reserves for the year ended December 31, 2008 decreased due primarily to a decrease in crude oil sales

prices. Proved developed producing crude oil reserves decreased by 213,000 barrels at December 31, 2008. The crude oil prices at the end of a

given year are one of the most significant factors used to determine the value of crude oil reserves. The average prices at December 31, 2008

declined by approximately $53.00 per barrel compared with the average prices at December 31, 2007. Based on these prices, many of the

Company's leases were uneconomic and no reserves were attributed to these leases.

Certain properties that the Company owns have become uneconomic and have been shut-down. When these properties are not

operated, any reserves that could be assigned to these properties are not included in the year-end engineering report of total Company reserves.

Another major factor that directly affects the Company's future reserve base is the price of crude oil at December 31, of any given year. The

year-end price of oil and gas has a significant impact on the estimated future net recoverable oil and gas reserves from proved developed

properties. At certain depressed price levels, some of the Company's oil and gas properties are not economical to operate and thus its year-end

engineering reserve reports do not assign any oil and gas reserves to these properties. Conversely, if year-end prices should increase to a

certain level, the reserves on these leases would be economic to produce and would increase the Company's reserves.

19
Forward-Looking Information

Looking forward into 2013, crude oil prices have increased by approximately $2.80 per barrel as of March 27, 2013, compared to

prices at December 31, 2012. There have been 56 separate price changes since December 31, 2012.

The Company is in the planning and permitting process to re-drill three of its existing wells sometime during the third quarter of

2013, depending on drilling rig availability. The three wells are located on the Company’s Delaney Tunnell property in Santa Maria,

California. Two will be production wells, and will be re-drilled into the Monterey formation at a depth of approximately 6,700 feet. The wells

were previously drilled to a depth of 4,700 feet. One of the wells will be re-drilled as a disposal well for production water. The Company has

submitted its water disposal plan to the State of California and is awaiting approval.

Management also will continue to evaluate external opportunities to grow the Company, and has maintained a strong balance sheet

and working capital position that could help facilitate potential future projects and transactions.

Pyramid's growth during 2013 and beyond will be highly dependent on the level of success the Company has in its operations and

capital investments, including the outcome of wells that have not yet been drilled. The Company's capital investment program may be modified

during the year due to exploration and development successes or failures, rig availability, market conditions and other variables. The

production and sales of oil and gas involves many complex processes that are subject to numerous uncertainties, including reservoir risk,

mechanical failures, human error and market conditions.

The Company has positioned itself, over the past several years, to withstand various types of economic uncertainties, with a program

of consolidating operations on certain producing properties and concentrating on properties that provide the major revenue sources. The

drilling of a new well and several limited work-overs of certain wells, have allowed the Company to maintain its crude oil reserves for the last

three years. The Company expects to maintain its reserve base in 2013, by drilling new wells and routine maintenance of its existing wells.

The Company may be subject to future costs necessary for compliance with the new implementation of air and water environmental

quality requirements of the various state and federal governmental agencies. The requirements and costs are unknown at this time, but

management believes that costs could be significant in some cases. As the scope of the requirements become more clearly defined,

management may be better equipped to determine the true costs to the Company.

The Company continues to absorb the costs for various state and local fees and permits under new environmental programs, the sum

of which, were not material during 2012. The Company retains outside consultants to assist the Company in maintaining compliance with

these regulations. The Company is actively pursuing an ongoing policy of upgrading and restoring older properties to comply with current and

proposed environmental regulations. The costs of upgrading and restoring older properties to comply with environmental regulations have not

been determined. Management believes that these costs will not have a material adverse effect on its financial position or results of operations.

20
ANALYSIS OF SIGNIFICANT CHANGES IN RESULTS OF OPERATIONS

Results Of Operations For The Fiscal Year Ended December 31, 2012

Compared To The Fiscal Year Ended December 31, 2011

Revenues

Oil and Gas Sales

Revenues decreased by $693,110 due primarily to lower crude oil production for 2012. Crude oil production/sales decreased by

approximately 6,900 barrels for 2012. Average prices of the Company's oil and gas sales increased by sixty cents per equivalent barrel when

compared to the same period for 2011.

Operating Expenses

Operating expenses increased by $153,185 for 2012 when compared to the same period for 2011. During 2012, the cost to produce

an equivalent barrel of crude oil was $40.98 per barrel, an increase of $8.02 per barrel when compared with production costs for the same

period of 2011. The increase in lease operating expenses is caused by many factors. Inventory change contributed to an increase in operating

expenses of $67,771. Costs increased for equipment fuel, well abandonments, chemicals, licenses and fees and gas engine repairs. These were

offset by lower costs for outside services.

Inventory change increased operating expenses by $35,976 for the twelve months ended December 31, 2012 and decreased operating

expenses by $31,795 for the twelve months ended December 31, 2011. As a result, operating expenses increased by $67,771 for the twelve

months ended December 31, 2012, when compared with the same period of 2011. The decrease in inventory at December 31, 2012 of

$35,976 is due primarily to lower inventory volumes at December 31, 2012 offset by higher average per unit values. The increase in inventory

at December 31, 2011 of $31,795 is due primarily to higher average per barrel inventory valuations offset by lower inventory volumes.

Equipment fuel costs increased by $44,758 due primarily to an increase in fuel consumed combined with higher average fuel costs

for gasoline and diesel used by the Company’s vehicles and production equipment. Well abandonment costs increased by $26,331 due to the

abandonment of three wells in 2012. One well was abandoned in 2011. Chemicals increased by $14,400 due primarily to higher usage of

chemicals on the Delaney-Tunnell lease. Licenses and permits increased by $13,714 due primarily to fees related to the Santa Fe lease. Gas

engine repairs increased by $11,755 due primarily to maintenance activities on the Santa Fe and Anderson wells. Outside services decreased

by $14,724 due to lower demand for third-party repair and maintenance services.

General and Administrative Expenses

General and administrative expenses decreased by $37,742 for the twelve months ended December 31, 2012 when compared with

the same period for 2011. Accounting services decreased by $62,442 due to lower audit fees and lower fees paid to a third-party who assisted

with the training and implementation of a new oil and gas accounting software that was effective January 1, 2011. Legal fees declined by

$26,027 during the twelve months ended December 31, 2012 due primarily to the filing of a Form S-8 during 2011. The legal fees expended

for the filing of the Form S-8 during 2011 were $17,500. Outside services increased by $16,852 due primarily to the hiring of temporary help

for the corporate office staff. General liability insurance increased by $10,425 due to an increase in the allocation of insurance costs to general

and administrative expense from operating expenses during 2012. General expenses increased by $8,000 due to a donation the Company made

during the second quarter of 2012 to a local medical facility. Administrative salaries increased by $6,077 due to a 7% wage rate increase that

was effective May 1, 2012. The remaining net increase in general and administrative costs of $9,353 is attributable to many different cost

categories, none of them significant in amount.

Stock Based Compensation

Effective June 2, 2011, the Company’s board of directors approved the issuance of options to purchase 5,000 shares of the

Company’s common stock to the Company’s two outside directors. These options vest immediately and must be exercised within ninety days

after the director leaves office. The Company recorded $43,743 in stock based compensation during the third quarter of 2011, based on a

valuation performed using a Black-Scholes option-pricing model.

Taxes, Other Than Income and Payroll Taxes

Taxes, other than income and payroll taxes increased by $22,981 due primarily to higher property taxes on the Company’s oil and

gas properties.

21
Provision for Depletion, Depreciation and Amortization

The provision for depletion, depreciation and amortization decreased by $85,673 for the twelve months ended December 31, 2012,

when compared with the same period for 2011. The amortization of Texas leaseholds decreased by approximately $48,000 during 2012. The

Texas leaseholds were fully amortized as of June 30, 2011. Depletion of oil and gas properties decreased by $32,600 for the twelve months

ended December 31, 2012. Depletion of oil and gas properties was lower due primarily to lower sales volumes for 2012.

Valuation Allowances

The Company recorded a valuation allowance of $237,711 at December 31, 2012 on certain of its oil and gas properties. The

valuation allowance resulted from an engineering reserve report that was prepared by MHA Petroleum Consultants, a third-part engineering

firm engaged by the Company.

Results Of Operations For The Fiscal Year Ended December 31, 2011

Compared To The Fiscal Year Ended December 31, 2010

Revenues

Oil and Gas Sales

Revenues increased by $1,173,226 due primarily to higher average prices offset by lower crude oil production for 2011. Average

prices of the Company's oil and gas sales increased by $28.74 per equivalent barrel when compared to the same period for 2010. Crude oil

production/sales decreased by approximately 5,000 barrels for 2011.

Operating Expenses

Operating expenses increased by $212,677 for 2011 when compared to the same period for 2010. During 2011, the cost to produce

an equivalent barrel of crude oil was $32.96 per barrel, an increase of $6.41 per barrel when compared with production costs for the same

period of 2010. The increase in lease operating expenses was caused by many factors. These include higher costs for labor, contract

operations, production equipment repair and maintenance, equipment fuel, chemicals, equipment rental and outside services. This was offset

by lower costs for parts and supplies and waste water disposal.

Labor costs increased by $62,483 due primarily to a change in capitalized labor costs. Company labor costs are capitalized for labor

activities that occur during the drilling of a new well or the redrilling of an existing well. During 2011, the Company drilled one new well and

in 2010 drilled one new well and redrilled two wells. During 2010, the Company capitalized approximately $72,000 of labor costs for the

drilling of these wells. In 2011, the Company capitalized approximately $14,500 of labor costs for the drilling of the one well, for a change of

$57,500. Labor costs also increased due to more overtime hours worked during 2011 when compared with 2010.

22
Contract operations increased by $44,148 due primarily to higher operating costs on the Wyoming joint venture operations due to

workovers on certain wells. Equipment repair and maintenance costs increased by $26,746 due primarily to higher maintenance levels on the

Company’s production equipment, pickups and trucks. Equipment fuel costs increased by $25,391 due primarily to an increase in average fuel

costs for gasoline and diesel used in the Company’s vehicles and production equipment. Chemical costs increased by $24,272 due to higher

volumes and types of chemicals used on a number of the Company’s oil and gas properties.

Equipment rental costs increased by $19,932 due primarily to activities related to the Pike lease. The Company leased a surface

pumping unit and a crude oil storage tank for the new 1-H well that was drilled in the first quarter of 2011. Outside services increased by

$16,908 due primarily to charges for the Mabry, Miller and Pike leases. During 2011, the Company employed a third-party contractor to

perform a gyro survey and another contractor to perform down-hole cement work on the Mabry #1 well. During 2011, the Company engaged

a third-party contractor to clear the surface area of the Miller fee property.

Parts and supplies decreased by $28,420 due to lower maintenance activities during 2011. Waste water disposal costs decreased by

$27,807 during 2011 due to lower costs on the Delaney Tunnell lease.

General and Administrative Expenses

General and administrative expenses increased by $4,881 during 2011 when compared with the same period for 2010. Accounting

services increased by $47,059 due to fees paid of $21,713 to a third-party individual to assist with the training and implementation of a new oil

and gas accounting software that was effective January 1, 2011. Audit fees were higher by $24,181 and tax consulting and tax preparation

services were higher by $5,531. Directors’ and officers’ liability insurance increased by $25,313. This insurance coverage was not effective

until October 1, 2010. Legal fees increased by $21,717 due primarily to the filing of a Registration Statement on Form S-8 that was filed in the

third quarter of 2011. These were offset by lower costs for consulting services and other office expenses. Consulting services declined by

$67,036 due to lower fees for consulting geologists. In 2010, the Company retained a geologist to review its oil and gas properties for future

well locations and this project was completed in 2010.

Stock Based Compensation

Effective June 2, 2011, the Company’s board of directors approved the issuance of options to purchase 5,000 shares of the

Company’s common stock to the Company’s two outside directors. These options vest immediately and must be exercised within ninety days

after the director leaves office. The Company recorded $43,743 in stock based compensation during the third quarter of 2011, based on a

valuation performed using a Black-Scholes option-pricing model.

On September 15, 2010, the Company and John Alexander entered into a Severance Award Agreement pursuant to which the

Company awarded Mr. Alexander a supplemental payment in connection with his future severance of employment with the Company and

recorded $113,500 in stock based compensation.

Provision for Depletion, Depreciation and Amortization

The provision for depletion, depreciation and amortization increased by $32,137 for the year ended December 31, 2011, when

compared with the same period for 2010. The increase is due primarily to an increase in depletion of the Company’s oil and gas properties.

The increase in depletion is due primarily to an increase in the depletion rate per barrel on the Santa Fe and the Anderson oil producing

properties for 2011. The depletion rate for these properties increased for 2011 due to a decrease in oil and gas reserves at December 31, 2010.

This was offset by a decline in the amortization of Texas leaseholds.

23
Valuation Allowances

During the third quarter of 2011, the Company recorded a valuation allowance of $673,000 against the costs of drilling the Pike 1-H

well. The Pike 1-H well was drilled in the first quarter of 2011 and has not responded favorably to efforts by the Company to stimulate

production from this well. The well is currently producing approximately 5 barrels per day. The Company’s share of the production from this

well is approximately 3.4 barrels per day. On March 21, 2011, the Company participated in the drilling of a joint venture well in Menard

County, Texas. Log analysis of this well indicated that the well would not be commercially viable, and was plugged and abandoned. The

Company owns a 30% interest in the joint venture. The Company recorded a valuation allowance of $54,384 against the costs incurred during

the six months ended June 30, 2011 for the drilling of this well.

CRITICAL ACCOUNTING POLICIES

Costs Incurred in Oil and Gas Producing Activities

The Company has adopted the "successful efforts" method of accounting for its oil and gas exploration and development activities, as

set forth in FASB ASC Topic 932.

The Company initially capitalizes expenditures for oil and gas property acquisitions until they are either determined to be successful

(capable of commercial production) or unsuccessful. The carrying value of all undeveloped oil and gas properties is evaluated periodically and

reduced if such carrying value appears to have been impaired. Leasehold costs relating to successful oil and gas properties remain capitalized

while leasehold costs which have been proven unsuccessful are charged to operations in the period the leasehold costs are proven

unsuccessful. Costs of carrying and retaining unproved properties are expensed as incurred.

The costs of drilling and equipping development wells are capitalized, whether the wells are successful or unsuccessful. The costs of

drilling and equipping exploratory wells are capitalized until they are determined to be either successful or unsuccessful. If the wells are

successful, the costs of the wells remain capitalized. If, however, the wells are unsuccessful, the capitalized costs of drilling the wells, net of

any salvage value, are charged to operations in the period the wells are determined to be unsuccessful.

The Company adopted FASB ASC Topic No. 360-10-15, "Accounting for the Impairment of Long-Lived Assets and for LongLived Assets to be Disposed of" (the Statement). The Statement specifies when an impairment loss should be recognized and how impairment

losses should be measured for long-lived assets to be held and used and for long-lived assets to be disposed of. In accordance with the

Statement, the costs of proved oil and gas properties and equipment are periodically assessed on a lease by lease basis to determine if such

costs exceed undiscounted future cash flows, and if conditions warrant an impairment reserve will be provided based on the estimated future

discounted cash flows. The Company recorded an impairment reserve of $237,771, $751,263 and $1,222,527 at December 31, 2012, 2011

and 2010, respectively (see Note 6 of Notes to Financial Statements included in Item 8 of this Form 10-K). The accumulated impairment

reserve was $4,980,931 and $7,743,220 at December 31, 2012 and 2011, respectively.

24
Depletion, Depreciation, and Amortization

Depletion of leasehold costs of producing oil and gas properties is provided on the unit-of-production method, by individual property

unit, based on estimated recoverable proved reserves. Depreciation and amortization of the costs of producing wells and related equipment are

provided on the unit-of-production method, by individual property unit, based on estimated recoverable proved developed reserves.

Amortization of the costs of undeveloped oil and gas properties is based on the Company's experience, giving consideration to the holding

periods of leaseholds. The average depletion per equivalent barrel of crude oil produced for 2012, 2011 and 2010 were $16.66, $24.27 and

$29.89, respectively.

Drilling and operating equipment, buildings, automotive, office and other property and equipment and leasehold improvements are

stated at cost. Depreciation and amortization are computed using the straight-line method over the shorter of the estimated useful lives or the

applicable lease terms (range of 3 to 19 years). Any permanent impairment of the carrying value of property and equipment is provided for at

the time such impairments become known.

Recent Accounting Pronouncements

In December 2011, the FASB issued ASU 2011-11, “Balance Sheet (Topic 210): Disclosures about Offsetting Assets and Liabilities”.

This ASU requires us to disclose both net and gross information about assets and liabilities that have been offset, if any, and the related

arrangements. The disclosures under this new guidance are required to be provided retrospectively for all comparative periods presented. We

are required to apply the amendments for annual reporting periods beginning on or after January 1, 2013, and interim periods within those

annual periods. The adoption of ASU 2011-11 is not expected to have a material impact on our financial position, results of operations or cash

flows.

In July 2012, the FASB issued ASU No. 2012-02, Intangibles – Goodwill and Other (Topic 350): Testing Indefinite-Lived Intangible

Assets for Impairment, which simplifies how entities test indefinite-lived intangible assets other than goodwill for impairment and permits an

entity to first assess qualitative factors to determine whether it is more likely than not that the fair value of the indefinite-lived intangible asset is

less than its carrying amount as a basis for determining whether it is necessary to perform a quantitative impairment test. This ASU is effective

for annual and interim impairment tests performed for fiscal years beginning after September 15, 2012 (early adoption is permitted). The

Company adopted this guidance and did not have a significant impact on the Company's consolidated financial position or results of

operations.

In October 2012, the FASB issued ASU 2012-04, “Technical Corrections and Improvements.” The amendments in this update cover

a wide range of Topics in the Accounting Standards Codification. These amendments include technical corrections and improvements to the

Accounting Standards Codification and conforming amendments related to fair value measurements. The amendments in this update will be

effective for fiscal periods beginning after December 15, 2012. The adoption of ASU 2012-04 is not expected to have a material impact on our

financial position, results of operations or cash flows.

Item 7A - Quantitative and Qualitative Disclosures About Market Risk

Not Applicable

25
Item 8 - Financial Statements and Supplementary Data

PYRAMID OIL COMPANY

INDEX TO FINANCIAL STATEMENTS

DECEMBER 31, 2012

Page

REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM 27

FINANCIAL STATEMENTS:

Balance sheets - December 31, 2012 and 2011 28

Statements of operations - years ended December 31, 2012, 2011 and 2010 30

Statements of shareholders' equity - years ended December 31, 2012, 2011 and 2010 31

Statements of cash flows - years ended December 31, 2012, 2011 and 2010 32

Notes to financial statements 34

26
REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM

To the Board of Directors and Shareholders

Pyramid Oil Company

Bakersfield, California

We have audited the balance sheets of Pyramid Oil Company (“the Company”) as of December 31, 2012 and 2011, and the related

statements of operations, shareholders' equity, and cash flows for each of the three years in the period ended December 31, 2012. 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 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 the financial statements are free of

material misstatement. The Company is not required to have, nor were we engaged to perform an audit of its internal control over financial

reporting. Our audit included consideration of internal control over financial reporting as a basis for designing audit procedures that are

appropriate in the circumstances, but not for the purpose of expressing an opinion on the effectiveness of the Company's internal control over

financial reporting. Accordingly, we express no such opinion. An audit also includes examining, on a test basis, evidence supporting the

amounts and disclosures in the financial statements, 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 provided a reasonable basis for our opinion.

In our opinion, the financial statements referred to above present fairly, in all material respects, the financial position of Pyramid Oil

Company as of December 31, 2012 and 2011, and the results of its operations and its cash flows for each of the three years in the period

ending December 31, 2012, in conformity with U. S. generally accepted accounting principles.

SINGERLEWAK LLP

Los Angeles, California

March 29, 2013

27
PYRAMID OIL COMPANY

BALANCE SHEETS

ASSETS

December 31,

2012 2011

CURRENT ASSETS:

Cash and cash equivalents $ 3,834,097 $ 2,762,676

Short-term investments 2,135,709 2,128,380

Trade accounts receivable (net of reserve for doubtful accounts of $4,000 in 2012 and 2011) 375,090 555,495

Income taxes receivable 73,069 21,169

Crude oil inventory 82,180 118,156

Prepaid expenses and other assets 257,370 255,846

Deferred Income taxes 264,400 262,500

TOTAL CURRENT ASSETS 7,021,915 6,104,222

PROPERTY AND EQUIPMENT, at cost:

Oil and gas properties and equipment (successful efforts method) 20,007,453 19,124,558

Capitalized asset retirement costs 425,978 401,242

Drilling and operating equipment 1,966,750 1,956,371

Land, buildings and improvements 1,098,918 1,073,918

Automotive, office and other property and equipment 1,202,544 1,192,118

24,701,643 23,748,207

Less - accumulated depletion, depreciation, amortization and valuation allowances (20,953,324) (20,091,655)

TOTAL PROPERTY AND EQUIPMENT 3,748,319 3,656,552

OTHER ASSETS

Long-term investments 1,101,526 1,071,984

Deferred income taxes 621,800 781,600

Deposits 250,000 250,000

Other assets 17,380 17,380

TOTAL OTHER ASSETS 1,990,706 2,120,964

TOTAL ASSETS $ 12,760,940 $ 11,881,738

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

28
PYRAMID OIL COMPANY

BALANCE SHEETS

LIABILITIES AND SHAREHOLDERS' EQUITY

December 31,

2012 2011

CURRENT LIABILITIES:

Accounts payable $ 226,759 $ 88,494

Accrued professional fees 120,000 142,990

Accrued taxes, other than income taxes 70,407 77,471

Accrued payroll and related costs 58,954 51,252

Accrued royalties payable 204,509 224,810

Accrued insurance 94,116 82,428

Current maturities of long-term debt 0 32,285

TOTAL CURRENT LIABILITIES 774,745 699,730

LONG-TERM DEBT, net of current maturities 0 22,330

LIABILITY FOR ASSET RETIREMENT OBLIGATIONS 1,327,861 1,278,889

TOTAL LIABILITES 2,102,606 2,000,949

COMMITMENTS AND CONTINGENCIES (Note 7)

SHAREHOLDERS' EQUITY:

Preferred stock, no par value

Authorized - 10,000,000 shares

Issued and outstanding – none 0 0

Common stock, no par value (Note 11, 12 and 13)

Authorized - 50,000,000 shares

Issued and outstanding - 4,688,085 shares

and 4,683,853 shares at December 31, 2012

and December 31, 2011, respectively 1,682,971 1,682,971

Retained earnings 8,975,363 8,197,818

TOTAL SHAREHOLDERS’ EQUITY 10,658,334 9,880,789

TOTAL LIABILITES AND SHAREHOLDERS’ EQUITY $ 12,760,940 $ 11,881,738

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

29
PYRAMID OIL COMPANY

STATEMENTS OF OPERATIONS

Year ended December 31,

2012 2011 2010

REVENUES:

Oil and gas sales $ 4,995,327 $ 5,688,437 $ 4,515,211

Gain on sales of property and equipment 0 1,512 320,556

4,995,327 5,689,949 4,835,767

COSTS AND EXPENSES:

Operating expenses 1,942,754 1,789,569 1,576,892

General and administrative 842,037 879,779 874,899

Stock based compensation 0 43,743 123,283

Taxes, other than income and payroll taxes 160,144 137,163 128,351

Provision for depletion, depreciation, and amortization 649,559 735,231 703,094

Valuation allowances 237,711 751,263 1,222,527

Accretion expense 38,341 45,314 34,955

Other costs and expenses 149,717 147,330 118,043

4,020,263 4,529,392 4,782,044

OPERATING INCOME 975,064 1,160,557 53,723

OTHER INCOME (EXPENSE):

Interest income 42,943 49,863 43,601

Other income (expense) 450 500 (14,061)

Interest expense (1,091) (3,020) (300)

42,302 47,343 29,240

INCOME BEFORE INCOME

TAX PROVISION (BENEFIT) 1,017,366 1,207,900 82,963

Income tax provision (benefit)

Current 81,921 203,203 109,100

Deferred 157,900 (90,500) (272,000)

239,821 112,703 (162,900)

NET INCOME $ 777,545 $ 1,095,197 $ 245,863

BASIC INCOME PER COMMON SHARE $ 0.17 $ 0.23 $ 0.05

DILUTED INCOME PER COMMON SHARE $ 0.17 $ 0.23 $ 0.05

Weighted average number of common shares outstanding 4,685,859 4,683,853 4,677,728

Diluted average number of common shares outstanding 4,685,859 4,687,580 4,686,003

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

30
PYRAMID OIL COMPANY

STATEMENTS OF SHAREHOLDERS' EQUITY

Common

Shares Total

Issued and Common Retained Shareholders’

Outstanding Stock Earnings Equity

Balances, December 31, 2009 4,677,728 $ 1,515,945 $ 6,856,758 $ 8,372,703

Severance award agreement 113,500 113,500

Stock based compensation 9,783 9,783

Net income 245,863 245,863

Balances, December 31, 2010 4,677,728 1,639,228 7,102,621 8,741,849

Stock based compensation 43,743 43,743

Shares issued on exercise of options 6,125

Net income 1,095,197 1,095,197

Balances, December 31, 2011 4,683,853 1,682,971 8,197,818 9,880,789

Shares issued on exercise of options 4,232

Net income 777,545 777,545

Balances, December 31, 2012 4,688,085 $ 1,682,971 $ 8,975,363 $ 10,658,334

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

31
PYRAMID OIL COMPANY

STATEMENTS OF CASH FLOWS

Year ended December 31,

2012 2011 2010

CASH FLOWS FROM OPERATING ACTIVITIES:

Net income $ 777,545 $ 1,095,197 $ 245,863

Adjustments to reconcile net income to net cash provided by operating activities:

Provision for depletion, depreciation, and amortization 649,559 735,231 703,094

Valuation allowances 237,711 751,263 1,222,527

Accretion expense 38,341 45,314 34,955

Gain on sale of property and equipment 0 (1,512) (320,556)

Loss on retirement of fixed assets 0 0 18,228

Stock based compensation 0 43,743 123,283

Deferred income taxes 157,900 (90,500) (272,000)

Asset retirement obligations 10,631 (1,618) 0

Changes in operating assets and liabilities:

(Increase) decrease in trade accounts and interest receivable 128,505 (68,207) (7,322)

(Increase) decrease in crude oil inventory 35,976 (31,795) (23,601)

(Increase) decrease in prepaid expenses (1,523) (24,970) (62,181)

(Increase) decrease in other assets 0 (10,000) 9,633

Increase (decrease) in accounts payable and accrued liabilities 107,300 55,099 56,999

Net cash provided by operating activities 2,141,945 2,497,245 1,728,922

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

32
PYRAMID OIL COMPANY

STATEMENTS OF CASH FLOWS

Year ended December 31,

2012 2011 2010

CASH FLOWS FROM INVESTING ACTIVITIES:

Capital expenditures $ (979,038) $ (1,163,961) $ (2,258,083)

Payments to acquire short-term investments 0 (100,000) (550,000)

(Increase) decrease in short-term investments (7,329) (11,655) 176,535

(Increase) in long-term investments (29,542) (30,181) (21,002)

Proceeds from redemption of short-term investments 0 0 680,000

Proceeds from sale of property and equipment 0 21,500 320,556

Net cash used in investing activities (1,015,909) (1,284,297) (1,651,994)

CASH FLOWS FROM FINANCING ACTIVITIES:

Proceeds from issuance of long-term debt 0 55,979 40,419

Principal payments on long-term debt (54,615) (41,783) (20,640)

Net cash provided by (used in) financing activities (54,615) 14,196 19,779

Net increase in cash and cash equivalents 1,071,421 1,227,144 96,707

Cash and cash equivalents at beginning of year 2,762,676 1,535,532 1,438,825

Cash and cash equivalents at end of year $ 3,834,097 $ 2,762,676 $ 1,535,532

SUPPLEMENTAL CASH FLOW INFORMATION:

Cash paid during the year for interest $ 1,091 $ 3,020 $ 300

Cash paid during the year for income taxes $ 133,821 $ 216,874 $ 1,000

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

33
PYRAMID OIL COMPANY

NOTES TO FINANCIAL STATEMENTS

DECEMBER 31, 2012

1. Significant Accounting Policies

Nature of Operations

Pyramid Oil Company (the Company), a California Corporation, has been in the oil and gas business continuously for 102 years

since it was incorporated on October 9, 1909. The Company is in the business of exploration, development and production of crude oil and

natural gas. The Company operated and has interests in 28 oil and gas leases in Kern and Santa Barbara Counties in the State of California.

The Company also owns oil and gas interests in Wyoming, Texas and New York that it does not operate. The Company grants short-term

credit to its customers and generally receives payment within 30 days.

Use of Estimates

The preparation of financial statements in conformity with accounting principles generally accepted in the United States requires

management to make estimates and assumptions that affect the reported amounts of assets and liabilities, disclosure of contingent assets and

liabilities at the date of the financial statements and the reported amounts of revenues and expenses during the reporting period. Actual results

could differ from those estimates.

Cash and Cash Equivalents

Cash and cash equivalents principally consist of demand deposits and certificates of deposits having original maturities of three

months or less. At December 31, 2012, the Company had approximately $3,578,553 of cash and cash equivalents that were not fully insured

by the FDIC.

Investments

Investments consist of certificates of deposit having original maturities of three months or more and are valued at cost.

Inventory

Inventories of crude oil and condensate are valued at the lower of cost, predominately on a first-in, first-out (FIFO) basis, or market,

and include certain costs directly related to the production process.

Deposits

In April 2004, the Company replaced its state of California oil and gas blanket performance surety bond, with a cash bond in the

form of an irrevocable certificate of deposit in the amount of $250,000.

34
PYRAMID OIL COMPANY

NOTES TO FINANCIAL STATEMENTS (Continued)

DECEMBER 31, 2012

Costs Incurred in Oil and Gas Producing Activities

The Company has adopted the "successful efforts" method of accounting for its oil and gas exploration and development activities, as

set forth in FASB ASC Topic No. 932.

The Company initially capitalizes expenditures for oil and gas property acquisitions until they are either determined to be successful

(capable of commercial production) or unsuccessful. The carrying value of all undeveloped oil and gas properties is evaluated periodically and

reduced if such carrying value appears to have been impaired. Leasehold costs relating to successful oil and gas properties remain capitalized

while leasehold costs which have been proven unsuccessful are charged to operations in the period the leasehold costs are proven

unsuccessful. Costs of carrying and retaining unproved properties are expensed as incurred.

The costs of drilling and equipping development wells are capitalized, whether the wells are successful or unsuccessful. The costs of

drilling and equipping exploratory wells are capitalized until they are determined to be either successful or unsuccessful. If the wells are

successful, the costs of the wells remain capitalized. If, however, the wells are unsuccessful, the capitalized costs of drilling the wells, net of

any salvage value, are charged to operations in the period the wells are determined to be unsuccessful.

The Company adopted FASB ASC Topic No. 360-10-15, "Accounting for the Impairment of Long-Lived Assets and for LongLived Assets to be Disposed of" (the Statement). The Statement specifies when an impairment loss should be recognized and how impairment

losses should be measured for long-lived assets to be held and used and for long-lived assets to be disposed of. In accordance with the

Statement, the costs of proved oil and gas properties and equipment are periodically assessed on a lease by lease basis to determine if such

costs exceed undiscounted future cash flows, and if conditions warrant an impairment reserve will be provided based on the estimated future

discounted cash flows. The Company recorded an impairment reserve of $237,711, $751,263 and $1,222,527 at December 31, 2012, 2011

and 2010, respectively (see Note 6). The accumulated impairment reserve was $4,980,931 and $4,743,220 at December 31, 2012 and 2011,

respectively.

Joint Venture Investments

The Company participates in two joint ventures as a non-operator. The properties are located in New York and Texas, both are

primarily gas properties. The Company has a minority interest in both joint ventures. The Company's interest in the New York gas wells range

from 19 to 38 percent. The Company's interest in the Texas joint venture wells range from 3.125 to 6.25 percent. The Company records its

share of revenues, expenses and capital costs as provided to the Company by the joint-venture operators. The accounting policies for the joint

venture properties are consistent with the accounting policies that the Company uses for its wholly-owned properties.

The Company participated in one joint venture as the operator for the Pike 1-H well. The Company’s joint venture partner in this well

was Victory Oil. The Company’s share of the property was 68%. During December 2012, the Company purchased Victory Oil’s share of the

joint venture. These amounts were not material to the financial statements.

35
PYRAMID OIL COMPANY

NOTES TO FINANCIAL STATEMENTS (Continued)

DECEMBER 31, 2012

Depletion, Depreciation, and Amortization

Depletion of leasehold costs of producing oil and gas properties is provided on the unit-of-production method, by individual property

unit, based on estimated recoverable proved reserves. Depreciation and amortization of the costs of producing wells and related equipment are

provided on the unit-of-production method, by individual property unit, based on estimated recoverable proved developed reserves.

Amortization of the costs of undeveloped oil and gas properties is based on the Company's experience, giving consideration to the holding

periods of leaseholds. The average depletion per equivalent barrel of crude oil produced for 2012, 2011 and 2010 were $16.66, $24.27 and

$29.89, respectively.

Drilling and operating equipment, buildings, automotive, office and other property and equipment and leasehold improvements are

stated at cost. Depreciation and amortization are computed using the straight-line method over the shorter of the estimated useful lives or the

applicable lease terms (range of 3 to 19 years). Any permanent impairment of the carrying value of property and equipment is provided for at

the time such impairments become known.

Stock-based Compensation

We account for share-based awards in accordance with the provisions of FASB ASC Topic No. 718, Compensation - Stock

Compensation (ASC 718). Accordingly, we measure share-based compensation expense at the grant date, based on the fair value of the

award, and recognize the expense over the employee's requisite service period using the straight-line method. The measurement of share-based

compensation expense is based on several criteria including but not limited to the valuation model used and associated input factors, such as

expected term of the award, stock price volatility, risk free interest rate and award forfeiture rate. These inputs are subjective and are

determined using management's judgment. If differences arise between the assumptions used in determining share-based compensation

expense and the actual factors, which become known over time, we may change the input factors used in determining future share-based

compensation expense. Any such changes could materially impact our results of operations in the period in which the changes are made and in

periods thereafter. We elected to adopt the alternative transition method for calculating the tax effects of share-based compensation and

continue to use the simplified method in developing the expected term used for our valuation of share-based compensation in accordance with

ASC 718.

Maintenance and Repairs

Maintenance, repairs and replacement expenditures are charged to operations as incurred, while major renewals and betterments are

capitalized and depreciated over their useful lives.

36
PYRAMID OIL COMPANY

NOTES TO FINANCIAL STATEMENTS (Continued)

DECEMBER 31, 2012

Retirement or Disposal of Properties and Equipment

Costs and accumulated depletion, depreciation, amortization and valuation allowances of property and equipment retired, abandoned,

or otherwise disposed of are removed from the accounts upon disposal, and any resulting gain or loss is included in operations in the year of

disposition. However, upon disposal of a portion of an oil and gas property, any proceeds received are treated as a recovery of cost and no

gain or loss is recognized in the year of disposition.

Income Taxes

The Company uses the asset and liability method of accounting for income taxes. Under the asset and liability method, deferred tax

assets and liabilities are recognized for the future tax consequences attributable to differences between the financial statement carrying amounts

of existing assets and liabilities and their respective tax bases. Deferred tax assets and liabilities are measured using enacted tax rates expected

to apply to taxable income in the years in which those temporary differences are expected to be recovered or settled. The effect on deferred tax

assets and liabilities of a change in tax rates is recognized in the period that includes the enactment date.

The Company adopted the provisions of FASB ASC Topic No. 740-10-25,” Accounting for Uncertainty in Income Taxes”, on

January 1, 2007 (ASC 740-10-25). As a result of the implementation of ASC 740-10-25, the company made a comprehensive review of its

portfolio of tax positions in accordance with recognition standards established by ASC 740-10-25. As a result of the implementation of ASC

740-10-25, the Company recognized no material adjustments to liabilities or stockholders equity.

The Company files income tax returns in the U.S. Federal jurisdiction, and California, Texas and New York states. With few

exceptions, the Company is no longer subject to U.S. Federal tax examination for the years prior to 2009. State jurisdictions that remain

subject to examination range from 2008 to 2011. The Company does not believe there will be any material changes in its unrecognized tax

positions over the next 12 months.

The Company’s policy is to recognize interest and penalties accrued on any unrecognized tax benefits as a component of income tax

expense. As of the date of adoption of ASC 740-10-25, the Company did not have any accrued interest or penalties associated with any

unrecognized tax benefits, nor was any interest expense recognized during the year ended December 31, 2012.

Concentration of Credit Risk

The Company sells its crude oil to Phillips 66 and Kern Oil & Refining, accounting for approximately 51%, and 47%, respectively,

of the Company’s crude oil and gas sales in 2012. Crude oil sales were approximately 50% and 47% attributable to Phillips 66 and Kern Oil

and Refining, respectively at December 31, 2011. While revenue from these customers is significant, and the loss of any one could have an

adverse effect on the Company, it is management's opinion that the oil and gas it produces could be sold to other crude oil purchasers,

refineries or pipeline companies. Trade receivables were approximately 62% and 37.5% attributable to Phillips 66 and Kern Oil and Refining,

respectively at December 31, 2012. Trade receivables were approximately 54% and 45% attributable to Phillips 66 and Kern Oil and Refining,

respectively at December 31, 2011.

37
PYRAMID OIL COMPANY

NOTES TO FINANCIAL STATEMENTS (Continued)

DECEMBER 31, 2012

Recent Accounting Pronouncements

In December 2011, the FASB issued ASU 2011-11, “Balance Sheet (Topic 210): Disclosures about Offsetting Assets and Liabilities”.

This ASU requires us to disclose both net and gross information about assets and liabilities that have been offset, if any, and the related

arrangements. The disclosures under this new guidance are required to be provided retrospectively for all comparative periods presented. We

are required to apply the amendments for annual reporting periods beginning on or after January 1, 2013, and interim periods within those

annual periods. The adoption of ASU 2011-11 is not expected to have a material impact on our financial position, results of operations or cash

flows.

In July 2012, the FASB issued ASU No. 2012-02, Intangibles – Goodwill and Other (Topic 350): Testing Indefinite-Lived Intangible

Assets for Impairment, which simplifies how entities test indefinite-lived intangible assets other than goodwill for impairment and permits an

entity to first assess qualitative factors to determine whether it is more likely than not that the fair value of the indefinite-lived intangible asset is

less than its carrying amount as a basis for determining whether it is necessary to perform a quantitative impairment test. This ASU is effective

for annual and interim impairment tests performed for fiscal years beginning after September 15, 2012 (early adoption is permitted). The

Company adopted this guidance and did not have a significant impact on the Company's consolidated financial position or results of

operations.

In October 2012, the FASB issued ASU 2012-04, “Technical Corrections and Improvements.” The amendments in this update cover

a wide range of Topics in the Accounting Standards Codification. These amendments include technical corrections and improvements to the

Accounting Standards Codification and conforming amendments related to fair value measurements. The amendments in this update will be

effective for fiscal periods beginning after December 15, 2012. The adoption of ASU 2012-04 is not expected to have a material impact on our

financial position, results of operations or cash flows.

Reclassifications

Certain reclassifications have been made to the prior financial statements to conform to the 2012 presentation.

Revenue Recognition

The Company recognizes sales when: (1) persuasive evidence of an arrangement exists; (2) product delivery has occurred; (3) pricing

is fixed or determinable; and (4) collection is reasonably assured. To satisfy these criteria, the Company: (1) has crude oil sales contracts with

its crude oil purchasers; (2) records revenue based upon receipt of evidence of shipment of crude oil and when risk of loss and title transfer

has occurred; (3) the Company's crude oil contracts specify the pricing terms which are fixed and determinable; (4) validates creditworthiness

through past payment history and other financial date. Sales rebates, discounts and customer returns are not applicable to the oil and gas

industry.

38
PYRAMID OIL COMPANY

NOTES TO FINANCIAL STATEMENTS (Continued)

DECEMBER 31, 2012

Trade Accounts Receivable and Allowance for Doubtful Accounts

Our accounts receivable are unsecured and are at risk to the extent such amounts become uncollectible. The Company has had the

same two major customers for approximately 20 years with no history of non-payment or default. Pursuant to the terms of the crude oil sales

contracts, the Company receives payment around the 20th of the month following crude oil shipments. The Company has established a

nominal allowance for doubtful accounts due to the Company's evaluation of its customers past payment history, creditworthiness and other

financial data.

Property and Equipment

Property and equipment are carried at cost less accumulated depreciation and amortization. Depreciation is recorded on the straightline basis over the estimated useful lives of the assets, which range from 3 to 19 years. Maintenance and repairs are charged to operations as

incurred, while significant improvements are capitalized. Upon retirement or disposition of property, the asset and related accumulated

depreciation or amortization is removed from the accounts and any resulting gain or loss is charged to operations. The carrying value of

property and equipment is assessed periodically and/or when factors indicating impairment are present. We recognize impairment losses when

the expected cash flows are less than the asset's carrying value, in which case the asset is written down to its estimated fair value. The

Company recorded an impairment reserve of $237,711, $751,263 and $1,222,527 at December 31, 2012, 2011 and 2010, respectively (see

Note 6).

2. Fair Value Measurements

Effective January 1, 2008, the Company adopted the authoritative guidance on fair value measurements. Fair value is defined as an

exit price, representing the amount that would be received to sell an asset or paid to transfer a liability in an orderly transaction between market

participants. As such, fair value is a market based measurement that should be determined based on assumptions that market participants

would use in pricing an asset or a liability. As a basis for considering such assumptions, the guidance establishes a three tier value hierarchy,

which prioritizes the inputs used in the valuation methodologies in measuring fair value:

Level 1 - Observable inputs that reflect quoted prices (unadjusted) for identical assets or liabilities in active markets.

Level 2 - Include other inputs that are directly or indirectly observable in the marketplace.

Level 3 - Unobservable inputs which are supported by little or no market activity. Included in this category is the Company’s valuation

of its asset retirement obligation liability. The obligation increased $48,972 during the year ended December 31, 2012, as a result of

normal accretion, the drilling of a new well, the purchase of two wells and the retirement of one well.

39
PYRAMID OIL COMPANY

NOTES TO FINANCIAL STATEMENTS (Continued)

DECEMBER 31, 2012

The fair value hierarchy also requires an entity to maximize the use of observable inputs and minimize the use of unobservable inputs

when measuring fair value.

In accordance with this guidance, we measure our cash equivalents and short-term investments at fair value. Our cash equivalents and

short term investments are classified within Level 1. Cash equivalents and short term investments are valued primarily using quoted market

prices utilizing market observable inputs. At December 31, 2012, cash equivalents and short term investments consisted of certificates of

deposit measured at fair value on a recurring basis. Fair values of our certificates of deposit were $3,642,944, of which $405,709 was

included in cash equivalents, $2,135,709 was included in short-term investments and $1,101,526 was included in long-term investments at

December 31, 2012. Fair values of our certificates of deposit were $3,605,658, of which $405,294 was included in cash equivalents,

$2,128,380 was included in short-term investments and $1,071,984 was included in long-term investments at December 31, 2011. The

carrying value of accounts receivable, accounts payable and accrued expenses approximates fair value because of the short maturity of those

instruments.

Fair Value on a Nonrecurring Basis

Certain assets and liabilities are measured at fair value on a nonrecurring basis in accordance with GAAP (for example, when there is evidence

of impairment). The amounts below represent only balances measured at fair value during the period presented and still held as of the reporting

date. These balances appear as a component of the “Oil and Gas Properties and Equipment” and “Accumulated Depletion, Depreciation,

Amortization and Valuation Allowances” captions on the balance sheet.

At and for the period ended December 31, 2012:

Total Level 1 Level 2 Level 3

Total

Valuation

Oil and gas properties and equipment $ 1,019,100 $ — $ — $ 781,400 $ (237,700)

In the year ended December 31, 2012 certain oil and gas properties and equipment held and used with a carrying amount of

$1,019,100 were written down to their fair value of $781,400, resulting in a valuation charge of $237,700, which was included in earnings for

this period. The fair value of these long-lived assets held and used was calculated based upon discounted cash flow projections. These

projections incorporate management's assumptions about future cash flows based upon past experience and future expectations. The expected

cash flows are then discounted using a discount rate that the Company believes is commensurate with the risks involved.

40
PYRAMID OIL COMPANY

NOTES TO FINANCIAL STATEMENTS (Continued)

DECEMBER 31, 2012

At and for the period ended December 31, 2011:

Total Level 1 Level 2 Level 3

Total

Valuation

Oil and gas properties and equipment $ 975,000 $ — $ — $ 224,000 $ (751,000)

In the year ended December 31, 2011 certain oil and gas properties and equipment held and used with a carrying amount of $975,000

were written down to their fair value of $224,000, resulting in a valuation charge of $751,000, which was included in earnings for this period.

The fair value of these long-lived assets held and used was calculated based upon discounted cash flow projections. These projections

incorporate management's assumptions about future cash flows based upon past experience and future expectations. The expected cash flows

are then discounted using a discount rate that the Company believes is commensurate with the risks involved.

3. Long-Term Debt and Line of Credit

Long-term debt at December 31, 2012 and 2011 is summarized as follows:

December 31,

2012 2011

Note payable to Ally, secured by equipment purchased with the proceeds of the loan, payable in monthly

installments of $1,627 principal and interest, interest at 2.9%, final payment in 2012. $ 0 $ 33,283

Note payable to ALLY, secured by equipment purchased with the proceeds of the loan, payable in

monthly installments of $1,123 principal and interest, interest at 0.0%, final payment in 2012. 0 21,332

0 54,615

Less - current maturities 0 32,285

$ 0 $ 22,330

At December 31, 2012, the Company had an unsecured line of credit with a bank, under which the Company may borrow up to

$500,000 through May 31, 2013. Interest on any borrowing is accrued at the bank's index rate plus 0.50 percentage points. The bank's index

rate was 4.75% at December 31, 2012.

41
PYRAMID OIL COMPANY

NOTES TO FINANCIAL STATEMENTS (Continued)

DECEMBER 31, 2012

4. Income Taxes

Income tax provision (benefit) consists of the following:

Year Ended December 31,

2012 2011 2010

Federal income taxes:

Current $ 69,700 $ 174,403 $ 92,000

Deferred 122,850 (70,350) (211,700)

192,550 104,053 (119,700)

State income taxes:

Current 12,221 28,800 17,100

Deferred 35,050 (20,150) (60,300)

47,271 8,650 (43,200)

Income tax provision (benefit) $ 239,821 $ 112,703 $ (162,900)

Differences exist between certain accounting policies and related provisions included in federal income tax rules. The amounts by

which these differences and other factors cause the total income tax provision to differ from an amount computed by applying the federal

statutory income tax rate to financial income is set forth in the following reconciliation:

Year Ended December 31,

2012 2011 2010

Federal income tax expense (benefit) at statutory rate $ 351,395 $ 410,686 $ 28,207

Statutory depletion (143,291) (320,627) (169,589)

Prior period tax changes (8,000) 0 0

State income taxes 12,221 28,800 17,100

Other 27,496 (6,156) (38,618)

Income tax provision (benefit) $ 239,821 $ 112,703 $ (162,900)

42
PYRAMID OIL COMPANY

NOTES TO FINANCIAL STATEMENTS (Continued)

DECEMBER 31, 2012

The components of net deferred tax asset (liability) are as follows:

Year Ended December 31,

2012 2011 2010

Current deferred taxes:

Gross assets $ 264,400 $ 262,500 $ 245,100

Gross liabilities 0 0 0

264,400 262,500 245,100

Noncurrent deferred taxes:

Gross assets 2,340,500 2,500,300 2,474,700

Gross liabilities 0 0 0

Valuation allowance (1,718,700) (1,718,700) (1,766,200)

621,800 781,600 708,500

$ 886,200 $ 1,044,100 $ 953,600

The tax effect of significant temporary differences representing deferred tax assets and (liabilities) are as follows:

Year Ended December 31,

2012 2011 2010

Accounts receivable $ 1,600 $ 1,600 $ 1,600

Asset retirement obligations 519,800 500,100 482,700

Statutory depletion carryover 1,718,700 1,718,700 1,766,200

Accrued liabilities 262,800 260,900 243,500

Total deferred tax assets 2,502,900 2,481,300 2,494,000

Property and equipment 102,000 281,500 225,800

Valuation allowance (1,718,700) (1,718,700) (1,766,200)

$ 886,200 $ 1,044,100 $ 953,600

At December 31, 2012, a valuation allowance has been provided against the statutory depletion carryover due to the uncertainty of its

future utilization.

The Company believes that its estimate of deferred tax assets and determination to record a valuation allowance against the statutory

depletion carryover are critical accounting estimates because they are subject to, among other things, an estimate of future taxable income,

which is susceptible to change and dependent upon events that may or may not occur, and because the impact of recording a valuation

allowance may be material to the assets reported on the balance sheet and results of operations.

43
PYRAMID OIL COMPANY

NOTES TO FINANCIAL STATEMENTS (Continued)

DECEMBER 31, 2012

At December 31, 2012, the Company has, for Federal income tax purposes, a statutory depletion carryover of approximately

$4,421,000, which currently has no expiration date.

The Company adopted the provisions of FASB ASC Topic No. 740-10-25 (ASC 740-10-25), Accounting for Uncertainty in Income

Taxes, on January 1, 2007. As a result of the implementation of ASC 740-10-25, the Company made a comprehensive review of its portfolio

of tax positions in accordance with recognition standards established by ASC 740-10-25. As a result of the implementation of ASC 740-10-

25, the Company recognized no material adjustments to liabilities or stockholders’ equity.

The Company files income tax returns in the U.S. Federal jurisdiction, and California, Texas and New York states. With few

exceptions, the Company is no longer subject to U.S. Federal tax examination for the years prior to 2009. State jurisdictions that remain

subject to examination range from 2008 to 2011. The Company does not believe there will be any material changes in its unrecognized tax

positions over the next 12 months.

The Company’s policy is to recognize interest and penalties accrued on any unrecognized tax benefits as a component of income tax

expense. As of the date of adoption of ASC 740-10-25, the Company did not have any accrued interest or penalties associated with any

unrecognized tax benefits, nor was any interest expense recognized during the year ended December 31, 2012.

5. Related-Party Transaction

Effective January 1, 1990, John H. Alexander, an officer and director of the Company participated with a group of investors that

acquired the mineral and fee interest on one of the Company's oil and gas leases (Santa Fe Energy lease) in the Carneros Creek field after the

Company declined to participate. The thirty-three percent interest owned by Mr. Alexander represents a minority interest in the investor group.

Royalties on oil and gas production from this property paid to the investor group approximated $222,500, $226,200 and $195,000 in 2012,

2011 and 2010, respectively.

As a director, Mr. Alexander has abstained from voting on any of the above matters that have been brought before the Board of

Directors, involving the Santa Fe lease. See Note 12 for discussion of severance awards entered into with Mr. Alexander.

6. Fourth Quarter Results (Unaudited)

During the fourth quarter of 2012, the Company made adjustments to the carrying value of some of its oil and gas properties. The

Company recorded a valuation allowance in the amount of $237,711 at December 31, 2012 to reflect the change in the projected future

discounted net cash flows for this property, as the result of the analysis of the Company's oil and gas reserves by independent consultants. The

Company also reduced depletion of its oil and gas properties by $39,414 as a result of the analysis of the Company's oil and gas reserves by

independent consultants at December 31, 2012.

44
PYRAMID OIL COMPANY

NOTES TO FINANCIAL STATEMENTS (Continued)

DECEMBER 31, 2012

During the fourth quarter of 2011, the Company made adjustments to the carrying value of one of its oil and gas properties. The

Company recorded a valuation allowance in the amount of $23,879 at December 31, 2010 to reflect the change in the projected future

discounted net cash flows for this property, as the result of the analysis of the Company's oil and gas reserves by independent consultants.

During the fourth quarter of 2010, the Company made adjustments to the carrying value of some of its oil and gas properties. The

Company recorded a valuation allowance in the amount of $237,647 at December 31, 2010 to reflect the change in the projected future

discounted net cash flows for this property as the result of the analysis of the Company's oil and gas reserves by independent consultants.

During the fourth quarter of 2010, the Company recorded a valuation allowance of $117,412 against one of the Company's joint venture wells

in Texas. The Company also recorded additional depletion of $27,010 on its oil and gas properties as a result of the analysis of the Company's

oil and gas reserves by independent consultants at December 31, 2010.

7. Commitments and Contingencies

The Company is liable for future dismantlement and abandonment costs associated with its oil and gas properties. These costs include

down-hole plugging and abandonment of wells, future site restoration, post closure and other environmental exit costs. The costs of future

dismantlement and abandonment have been accrued and recorded in the financial statements. See Note 10, Assets Retirement Obligations.

The Company is subject to potential litigation within the normal course of business. In management's opinion, the resolution of such

litigation would not have a material adverse effect upon the Company's financial position or the results of its operations. The Company did not

have any pending litigation at December 31, 2012.

In February 2002, the Company entered into an employment agreement with John H. Alexander pursuant to which Mr. Alexander

agreed to serve as the Company's Vice President. On June 3, 2004, Mr. Alexander was appointed as the Company's President and Chief

Executive Officer. The employment agreement is for an initial term of six years, which term automatically renews annually if written notice is

not tendered.

Pursuant to the employment agreement, the Company may terminate Mr. Alexander's employment with or without cause at any time

before its term expires upon providing written notice. In the event the Company terminates Mr. Alexander's employment without cause, Mr.

Alexander would be entitled to receive a severance amount equal to his annual base salary and benefits for the balance of the term of his

employment agreement. In the event of termination by reason of Mr. Alexander's death or permanent disability, his legal representative will be

entitled to receive his annual salary and benefits for the remaining term of his employment agreement. In the event of, or termination following,

a change in control of the Company, as defined in the agreement, Mr. Alexander would be entitled to receive his annual salary and benefits for

the remainder of the term of his agreement. In the event that Mr. Alexander is terminated the Company would incur approximately $870,000 in

costs.

45
PYRAMID OIL COMPANY

NOTES TO FINANCIAL STATEMENTS (Continued)

DECEMBER 31, 2012

The Company has been notified by the United States Environmental Protection Agency (EPA) of a final settlement offer to settle its

potential liability as a generator of waste containing hazardous substances that were disposed of at a waste disposal site in Santa Barbara

County. The Company has responded to the EPA by indicating that the waste contained petroleum products that fall within the exception to the

definition of hazardous substances for petroleum-related substances of the pertinent EPA regulations. Management has concluded that under

both Federal and State regulations no reasonable basis exists for any valid claim against the Company. As such, the likelihood of any

settlement is deemed remote.

During the fourth quarter of 2012, pursuant to requirements of the California Department of Oil and Gas (CA DOG) the Company

conducted a testing program on all of its crude oil storage tanks. The testing required the Company to empty each tank and measure for the

thickness of the metal. The testing is almost complete and the results were favorable. The testing process disrupted crude oil production during

the fourth quarter leading to lower revenues.

8. Gain on Sale of Fixed Assets

During 2011, the Company recognized a gain of $1,512 on the sale of a Company owned vehicle. On July 28, 2010, the Company

entered into a Purchase and Sale Agreement for the sale of a portion of its Texas joint venture leaseholds. Pursuant to the agreement, the

Company agreed to sell to the buyers 5% of the working interest of the Company's Texas joint venture, subject to certain prior agreements and

encumbrances. The purchase price for the assigned interest is $320,566. After the sale, the Company continues to own a 7.5% working

interest in the assets. The Company recognized a gain on the sale of the Texas leasehold interests in the amount of $320,566. The leasehold

interests had been previously fully amortized.

9. Defined Contribution Plan

The Company has a defined contribution plan (Simple IRA) available to all employees meeting certain service requirements.

Employees may contribute up to a maximum of $6,000 of their compensation to the plan. The Company will make a contribution to the plan in

an amount equal to the employee’s contributions up to 3% of their salaries. Contributions of $12,646, $11,549 and $9,521 were made during

the years ended December 31, 2012, 2011 and 2010, respectively.

46
PYRAMID OIL COMPANY

NOTES TO FINANCIAL STATEMENTS (Continued)

DECEMBER 31, 2012

10. Asset Retirement Obligations

The Company recognizes a liability at discounted fair value for the future retirement of tangible long-lived assets and associated

assets retirement cost associated with the petroleum and natural gas properties. The fair value of the liability is capitalized as part of the cost of

the related asset and amortized to expense over its useful life. The liability accretes until the date of expected settlement of the retirement

obligations. The related accretion expense is recognized in the statement of operations. The provision will be revised for the effect of any

changes to timing related to cash flow or undiscounted abandonment costs. Actual expenditures incurred for the purpose of site reclamation

are charged to the asset retirement obligations to the extent that the liability exists on the balance sheet. Differences between the actual costs

incurred and the fair value of the liability recorded are recognized in income in the period the actual costs are incurred.

There are no legally restricted assets for the settlement of asset retirement obligations. The Company has recognized deferred tax

benefits of approximately $519,800 for the asset retirement obligations as of December 31, 2012.

A reconciliation of the Company's asset retirement obligations from the periods presented, are as follows:

December 31,

2012 2011 2010

Beginning balance $ 1,278,889 $ 1,235,193 $ 1,193,324

Incurred during the period (14,105) (13,397) 0

Additions for new wells 25,092 11,779 6,942

Accretion expense 37,985 45,314 34,927

Ending balance $ 1,327,861 $ 1,278,889 $ 1,235,193

11. Stock Based Compensation

The Company issued warrants and options to purchase common shares of the Company as compensation for consulting and Board

of Directors services. The value of warrants and options issued for compensation are accounted for as a non-cash expense to the Company at

the fair value of the warrants and options issued. The Company values the warrants and options at fair value as calculated by using the BlackScholes option-pricing model. As of December 31, 2012 the Company has $0 in unamortized stock based compensation related to outstanding

options and warrants.

The Company has adopted FASB ASC Topic No. 718 (ASC 718) which requires the measurement and recognition of compensation

expense for all share-based payment awards made to employees, directors and consultants based on estimated fair values. ASC 718 requires

companies to estimate the fair value of the award that is ultimately expected to vest to be recognized as expense. ASC 718 requires companies

to estimate the fair value of share-based payment awards on the date of the grant using an option-pricing model. The value of the award that is

ultimately expected to vest is recognized as expense over the requisite service periods.

47
PYRAMID OIL COMPANY

NOTES TO FINANCIAL STATEMENTS (Continued)

DECEMBER 31, 2012

The Company's determination of fair value of share-based payment awards on the date of grant uses the Black-Scholes model, which

is affected by the Company's stock price as well as assumptions regarding a number of complex and subjective variables. These variables

include, but are not limited to, the expected stock price volatility over the expected term of the awards, and actual and projected option exercise

behaviors. The Company estimated expected volatility using historical data. The fair value of each warrant was estimated on the date of grant

using the Black-Scholes option-pricing model with the following assumptions:

Risk-free interest rate 1.19%

Expected term (years) 2.0

Volatility 135%

Expected annual dividends -

Stock price at November 13, 2008 $ 3.96

The following table summarizes the warrant and option activity for the twelve months ended December 31, 2012:

Number of

Warrants and

Options

Weighted-Average

Exercise Price

Outstanding, December 31, 2011 25,000 $ 4.08

Granted 0 0

Exercised (15,000) 4.46

Cancelled — 0

Outstanding, December 31, 2012 10,000 $ 5.40

The following summarizes the warrants issued, outstanding and exercisable as of December 31, 2011:

Grant Date November, 2008

Strike Price $3.20

Expiration Date October 31, 2012

Warrants Remaining 15,000

Proceeds if Exercised $48,000

Call Feature None

During 2010, the Company's Board of Directors approved the extension of the expiration date of the warrants from November of

2010 to November of 2011. The Company recorded stock based compensation of $9,783 for the period ended December 31, 2010 as a result

of the extension of the expiration date of the warrants. During 2011, the Company's Board of Directors approved the extension of the

expiration date of the warrants from November of 2011 to October 31 of 2012. There was no additional stock based compensation recorded

for this extension. On July 2, 2012 and September 20, 2012 consultants exercised the remaining 15,000 warrants under “cash-less” exercise

provisions of the warrant agreement. As a result, 4,232 share of common stock were delivered to the warrant holders.

48
PYRAMID OIL COMPANY

NOTES TO FINANCIAL STATEMENTS (Continued)

DECEMBER 31, 2012

The following summarizes the options issued, outstanding and exercisable as of December 31, 2012:

Grant Date June 2, 2011

Strike Price $5.40

Expiration Date June 1, 2016

Options Remaining 10,000

Proceeds if Exercised $54,000

Call Feature None

12. Severance Award Agreements

On September 15, 2010, the Company and John Alexander entered into a Severance Award Agreement pursuant to which the

Company awarded Mr. Alexander a supplemental payment in connection with his future severance of employment with the Company and

recorded an increase to stockholders' equity of $113,500. Pursuant to the Severance Award Agreement and following the termination of Mr.

Alexander's employment, he will be entitled to receive (at the Company's option) 25,000 shares of the Company's common stock or the thenfair market value of the shares. As of September 30, 2010, the Company intended to deliver the Company's common shares for the Severance

Award; the Company's common shares for the Severance Award; therefore, in accordance with ASC 718, management classified the sharebased compensation as stockholders' equity at December 31, 2010.

13. Incentive and Retention Plan

On January 9, 2007, the Company's Board of Directors adopted an Incentive and Retention Plan pursuant to which the Company's

officers and other employees selected by the Company's Compensation Committee are entitled to receive payments if they are employed by the

Company as of the date of a 'Corporate Transaction,' as defined in the Incentive and Retention Plan. A 'Corporate Transaction' includes certain

mergers involving the Company, sales of Company assets, and other changes in the control of the Company, as specified in the Incentive and

Retention Plan. In general, the amount that is payable to each plan participant will equal the number of plan units that have been granted to him

or her, multiplied by the increase in the value of the Company between January 9, 2007 and the date of a Corporate Transaction. There has

been no Corporate Transaction since the adoption of the Incentive and Retention Plan.

49
PYRAMID OIL COMPANY

NOTES TO FINANCIAL STATEMENTS (Continued)

DECEMBER 31, 2012

14. Registration Statement on Form S-3

The Company filed a shelf registration statement on Form S-3 with the Securities and Exchange Commission (SEC) on December

22, 2009, that became effective on January 14, 2010. The registration statement is designed to provide the Company the flexibility to offer and

sell from time to time up to $20 million of the Company's common stock. The Company may offer and sell such securities through one or

more methods of distribution, subject to market conditions and the Company's capital needs. The terms of any offering under the shelf

registration statement will be established at the time of such offering and will be described in a prospectus supplement filed with the SEC prior

to the completion of the offering. The Company has not filed any supplemental prospectus with the SEC or sold any common stock under this

registration statement. The registration statement on Form S-3 expired on January 14, 2013.

15. Subsequent Events

The Company evaluated subsequent events after the balance sheet date of December 31, 2012 through the date of filing this report.

50
PYRAMID OIL COMPANY

SUPPLEMENTAL INFORMATION (UNAUDITED) (Continued)

OIL AND GAS PRODUCING ACTIVITIES

DECEMBER 31, 2012

FASB ASC Topic 932, Extraction Activities - Oil and Gas, requires disclosure of certain financial data for oil and gas operations and

reserve estimates of oil and gas. This information, presented here, is intended to enable the reader to better evaluate the operations of the

Company. All of the Company's oil and gas reserves are located in the United States.

The aggregate amounts of capitalized costs relating to oil and gas producing activities and the related accumulated depletion,

depreciation, and amortization and valuation allowances as of December 31, 2012, 2011 and 2010 were as follows:

2012 2011 2010

Proved properties $ 19,828,900 $ 18,946,000 $ 17,922,900

Unproved properties being amortized 178,600 178,600 178,600

Unproved properties not being amortized 0 0 0

Capitalized asset retirement costs 426,000 401,200 389,500

Accumulated depletion, depreciation, amortization and valuation allowances (17,912,400) (17,132,100) (15,755,500)

$ 2,521,100 $ 2,393,700 $ 2,735,500

The estimated quantities and the change in proved reserves, both developed and undeveloped, for the Company are as follows:

2012 2011 2010

Oil Gas Oil Gas Oil Gas

(Mbbls) (MMCF) (Mbbls) (MMCF) (Mbbls) (MMCF)

Proved developed and undeveloped reserves:

Beginning of year 546 42 538 44 506 81

Revisions of previous estimates (19) (36) 63 7 92 (28)

Extensions, discoveries and other additions 0 0 0 0 0 0

Production (45) (6) (55) (9) (60) (9)

End of year 482 0 546 42 538 44

Proved developed reserves:

Beginning of year 474 42 433 35 383 43

End of year 482 0 474 42 433 35

Proved undeveloped reserves:

Beginning of year 71 0 105 8 123 38

End of year 0 0 71 0 105 8

The foregoing estimates have been prepared by the Company from data prepared by an independent petroleum engineer in respect to certain

producing properties. Revisions in previous estimates as set forth above can result from analysis of new information, as well as from

additional production experience or from a change in economic factors. The primary factor that has impacted the revisions of previous

estimates of crude oil and natural gas reserves noted above is from a change in crude oil and natural gas prices used to determine the valuation

of year-end reserves. Higher crude oil and natural gas prices cause certain oil and gas leases to become more profitable,thus generating

additional reserves. Net average crude oil sales prices (average crude oil sales prices net of operating costs, production taxes and development

costs) used to value the year-end reserves decreased by approximately $6.50 per barrel at December 31, 2012, and increased by approximately

$18.00 per barrel at December 31, 2011 and increased by approximately $12.60 per barrel at December 31, 2010.

51
PYRAMID OIL COMPANY

SUPPLEMENTAL INFORMATION (UNAUDITED) (Continued)

OIL AND GAS PRODUCING ACTIVITIES

DECEMBER 31, 2012

The decrease in revisions of previous estimates for natural gas reserves at December 31, 2010, is due primarily to one of the

Company's Texas joint venture wells. During 2010, this well started producing exclusively crude oil due to work that was done on this well in

2010.

The reserve estimates are believed to be reasonable and consistent with presently known physical data concerning size and character

of the reservoirs and are subject to change as additional knowledge concerning the reservoirs becomes available.

The present value of estimated future net revenues of proved developed and undeveloped reserves, discounted at 10%, were as

follows:

December 31,

2012 2011 2010

Proved developed and undeveloped reserves

(Present value before income taxes) $ 13,712,000 $ 18,439,000 $ 13,068,000

FASB ASC Topic 932, Extraction Activities - Oil and Gas, requires certain disclosures of the costs and results of exploration and

production activities and established a standardized measure of oil and gas reserves and the year-to-year changes therein.

In addition to the foregoing disclosures, FASB ASC Topic 932, Extraction Activities - Oil and Gas established a "Standardized

Measure of Discounted Future Net Cash Flows and Changes Therein Relating to Proved Oil and Gas Reserves".

Costs incurred, both capitalized and expensed, of oil and gas property acquisition, exploration and development for the years ended

December 31, 2012, 2011 and 2010 were as follows:

2012 2011 2010

Property acquisition costs $ 50,000 $ 700 $ 60,000

Exploration costs – expensed 0 0 0

Development costs 857,900 1,022,300 2,113,900

Asset retirement costs 24,700 11,800 6,900

52
PYRAMID OIL COMPANY

SUPPLEMENTAL INFORMATION (UNAUDITED) (Continued)

OIL AND GAS PRODUCING ACTIVITIES

DECEMBER 31, 2012

The results of operations for oil and gas producing activities for the years ended December 31, 2012, 2011 and 2010 were as

follows:

2012 2011 2010

Sales $ 4,995,000 $ 5,688,000 $ 4,515,000

Production costs 2,103,000 1,920,000 1,698,000

Exploration costs 0 0 0

Accretion expense 38,000 45,000 35,000

Depletion, depreciation, amortization and valuation allowance 887,000 1,486,000 1,819,000

1,967,000 2,237,000 963,000

Income tax (benefit) provision 240,000 113,000 (163,000)

Results of operations from production activities $ 1,727,000 $ 2,124,000 $ 1,126,000

The standardized measure of discounted estimated future net cash flows relating to proved oil and gas reserves for the years ended

December 31, 2012, 2011 and 2010 were as follows:

2012 2011 2010

Future cash inflows $ 51,004,000 $ 58,216,000 $ 41,973,000

Future development and production costs 25,941,000 24,445,000 19,454,000

Future abandonment costs 1,328,000 1,279,000 1,235,000

Future income tax expense 5,238,000 7,987,000 4,759,000

Future net cash flow 18,497,000 24,505,000 16,525,000

10% annual discount 7,771,000 9,392,000 6,368,000

Standardized measure of discounted future net cash flow $ 10,726,000 $ 15,113,000 $ 10,157,000

53
PYRAMID OIL COMPANY

SUPPLEMENTAL INFORMATION (UNAUDITED) (Continued)

OIL AND GAS PRODUCING ACTIVITIES

DECEMBER 31, 2012

The principal changes in the standardized measure of discounted future net cash flows during the years ended December 31, 2012,

2011 and 2010 were as follows:

2012 2011 2010

Extensions $ 0 $ 0 $ 0

Revisions of previous estimates

Price changes (2,155,000) 7,026,000 4,962,000

Quantity estimates (894,000) 1,901,000 2,016,000

Change in production rates, timing and other (1,642,000) (1,157,000) (2,136,000)

Development costs incurred 858,000 1,023,000 941,000

Changes in estimated future development costs (1,281,000) 315,000 (46,000)

Estimated future abandonment costs (6,000) 8,000 (4,000)

Sales of oil and gas, net of production costs (2,892,000) (3,768,000) (2,817,000)

Accretion of discount 1,922,000 1,386,000 994,000

(6,090,000) 6,734,000 3,910,000

Net change in income taxes (1,703,000) 1,778,000 1,106,000

Net (decrease) increase $ (4,387,000) $ 4,956,000 $ 2,804,000

Estimated future cash inflows are computed by applying year-end prices of oil and gas to year-end quantities of proved reserves.

Estimated future development and production costs are determined by estimating the expenditures to be incurred in developing and producing

the proved oil and gas reserves at the end of the year, based on year-end costs and assuming continuation of existing economic conditions.

Estimated future income tax expense is calculated by applying the year-end effective tax rate to estimated future pretax net cash flows related to

proved oil and gas reserves, less the tax basis of the properties involved.

These estimates are furnished and calculated in accordance with requirements of the Financial Accounting Standards Board and the

Securities and Exchange Commission. Because of the unpredictable variances in expenses and capital forecasts, crude oil and natural gas price

changes being largely influenced and controlled by United States and foreign governmental 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 do not

represent management's assessment of future profitability or future actual cash flows of the Company. It should be recognized that applying

current costs and prices and a ten percent standard discount rate allows for comparability but does not convey absolute value. The discounted

amounts arrived at are only one measure of financial quantification of proved reserves.

54
PYRAMID OIL COMPANY

SUPPLEMENTAL INFORMATION (UNAUDITED) (Continued)

OIL AND GAS PRODUCING ACTIVITIES

DECEMBER 31, 2012

The standardized measure of discounted future cash flows before income taxes decreased by $6,090,000 at December 31, 2012. The

decrease in income taxes offset discounted future cash flows by $1,703,000 for a net decrease in future cash flows of $4,387,000 after income

taxes as of December 31, 2012. The factors contributing to the decrease in cash flows are lower net average crude oil prices (average crude oil

sales prices net of operating costs, production taxes and development costs). During 2012, net average crude oil prices decreased by

approximately $6.50 per barrel. At December 31, 2012 the Company did not have any proved undeveloped reserves which also contributed to

the decrease in future cash flows for 2012. The proved undeveloped reserves at December 31, 2011 included two wells that were projected to

be drilled during 2012. One of these wells was the Santa Fe #20 development well that was drilled in 2012. This well is not currently

producing and a valuation allowance of $204,000 was recorded at December 31, 2012 for the Santa Fe energy lease. The other well project to

be drilled in 2012, the CLI 4-H, was not drilled during 2012 and is not expected to be drilled in the future.

The standardized measure of discounted future cash flows before income taxes increased by $6,734,000 at December 31, 2011. The

increase in income taxes offset discounted future cash flows by $1,778,000 for a net increase in future cash flows of $4,956,000 after income

taxes as of December 31, 2011. The major factor contributing to the increase in cash flows is higher net average crude oil prices (average

crude oil sales prices net of operating costs, production taxes and development costs). During 2011, net average crude oil prices increased by

approximately $18.00 per barrel. This price increase contributed to an increase in discounted cash flows due to price changes of $7,026,000.

The standardized measure of discounted future cash flows before income taxes increased by $3,910,000 at December 31, 2010. The

increase in income taxes offset discounted future cash flows by $1,106,000 for a net increase in future cash flows of $2,804,000 after income

taxes as of December 31, 2010. The major factor contributing to the increase in cash flows is higher net average crude oil prices (average

crude oil sales prices net of operating costs, production taxes and development costs). During 2010 Net average crude oil prices increased by

approximately $12.60 per barrel. This price increase contributed to an increase in discounted cash flows due to price changes of $4,962,000

and a change in quantity estimates of $2,016,000.

55
PYRAMID OIL COMPANY

SUPPLEMENTAL INFORMATION (UNAUDITED)

QUARTERLY RESULTS

2012 2011

REVENUES:

Quarter Ended:

March 31 $ 1,369,058 $ 1,327,310

June 30 1,340,314 1,549,029

September 30 1,198,420 1,412,842

December 31 1,087,535 1,400,768

$ 4,995,327 $ 5,689,949

NET INCOME (LOSS):

Quarter Ended:

March 31 $ 372,096 $ 319,642

June 30 288,571 427,023

September 30 (a) 207,896 4,263

December 31 (b) (91,018) 344,269

$ 777,545 $ 1,095,197

INCOME (LOSS) PER COMMON SHARE:

Quarter Ended:

March 31 $ 0.08 $ 0.07

June 30 0.06 0.09

September 30 (a) 0.04 0.00

December 31 (b) (0.01) 0.07

$ 0.17 $ 0.23

(a) Reflects a valuation allowance of $673,000 recorded in the third quarter of 2011 for the write-down of the costs of a well drilled in the first

quarter of 2011.

(b) Reflects a valuation allowance of $238,000 recorded in the fourth quarter of 2012 for the write-down of certain oil and gas properties.

56
PYRAMID OIL COMPANY

CORPORATE INFORMATION

Board of Directors Michael D. Herman, Chairman of the Board

John H. Alexander, President, Pyramid Oil Company

John E. Turco, Private Investor

Gary L. Ronning, former Executive Vice President, Western Region

Prime Natural Resources, LLC

Officers John H. Alexander, President

Lee G. Christianson, Secretary-Treasurer

Independent Auditor SingerLewak LLP - Los Angeles, California

Transfer Agent Computershare Investor Services

and Registrar 250 Royall St.

Canton, MA 02021

800-962-4284

Corporate Offices 2008-21st Street

Bakersfield, California 93301

District Offices Bakersfield, California

Legal Counsel TroyGould PC - Los Angeles, California

Investor Information Availability of Form 10-K: The Annual Report of

Pyramid Oil Company on Form 10-K, as filed with the

Securities and Exchange Commission, is available to any

stockholder upon request without charge. Please

address all such requests to:

Corporate Secretary

Pyramid Oil Company

P.O. Box 832

Bakersfield, California 93302

COMMON STOCK: The Company's common stock is traded on the NYSE MKT using the

symbol PDO.

57
Item 9 - Changes In and Disagreements with Accountants on Accounting and Financial Disclosure

None

Item 9A - Controls and Procedures

The Company maintains disclosure controls and procedures that are designed to ensure that information required to be disclosed in

the reports that the Company files with the Securities and Exchange Commission (the “SEC”) under the Securities Exchange Act of 1934 (the

“Exchange Act”) is recorded, processed, summarized and reported within the time periods specified in the SEC’s rules and forms and that

such information is accumulated and communicated to the Company’s management, including the principal executive and financial officers, as

appropriate, to allow for timely decisions regarding required disclosure. As required by SEC Rule 13a-15(b), the Company carried out an

evaluation, under the supervision and with the participation of its management, including its principal executive and financial officers, of the

effectiveness of the design and operation of the Company’s disclosure controls and procedures as of the end of the period covered by this

Annual Report. Based on the foregoing, the Company’s principal executive and financial officers concluded that the Company’s disclosure

controls and procedures are effective to ensure that the information required to be disclosed in the Company’s reports filed or submitted under

the Exchange Act is timely recorded, processed and reported within the time periods specified in the SEC’s rules and forms.

Management’s Report on Internal Control over Financial Reporting

This report is provided by the Company’s management pursuant to Section 404 of the Sarbanes-Oxley Act of 2002 and the SEC

rules promulgated thereunder. Management is responsible for establishing and maintaining adequate internal control over financial reporting

and for assessing the effectiveness of internal control over financial reporting.

The Company’s 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 Untied States. 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 Company’s assets; (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, and that the Company’s receipts and expenditures are being made only in

accordance with authorizations of the Company’s management and directors; and (iii) provide reasonable assurance regarding prevention or

timely detection of unauthorized acquisitions, 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.

Management has assessed the Company’s internal control over financial reporting as of December 31, 2012, based on criteria

established in Internal Control-Integrated Framework issued by the Committee of Sponsoring Organizations of the Treadway Commission

(COSO). Based on the assessment of the Company’s internal control over financial reporting, management has concluded that, as of

December 31, 2012, the Company’s internal control over financial reporting was effective.

58
Pursuant to applicable law, this annual report is not required to include an attestation report of the Company’s registered public

accounting firm regarding internal control over financial reporting.

There has been no change in the Company’s internal control over financial reporting during the Company’s most recent fiscal quarter

that has materially affected, or is reasonably likely to materially affect, the Company’s internal control over financial reporting.

Item 9B - Other Information

The Company is aware of no information that was required to be disclosed in a report on Form 8-K during the fourth quarter of 2012

but was not reported.

PART III

Item 10 - Directors, Executive Officers and Corporate Governance

The Company hereby incorporates by reference the information to be contained under the section entitled "Directors and Executive

Officers" or a similarly entitled section from its definitive Proxy Statement to be filed with the Securities and Exchange Commission in

connection with its 2013 Annual Meeting of Shareholders.

The Company has adopted a code of ethics that is applicable to all of its directors, officers and employees. A copy of the code is

available at no charge to any person who sends a request for a copy to the Corporate Secretary, Pyramid Oil Company, P.O. Box 832,

Bakersfield, California 93302.

Item 11 - Executive Compensation

The Company hereby incorporates by reference the information to be contained under the section entitled "Compensation of Directors

and Executive Officers" or a similarly entitled section from its definitive Proxy Statement to be filed with the Securities and Exchange

Commission in connection with its 2013 Annual Meeting of Shareholders.

Item 12 - Security Ownership of Certain Beneficial Owners and Management and Related Stockholder Matters

The Company hereby incorporates by reference the information to be contained under the section entitled "Voting Securities and

Principal Holders Thereof" or a similarly entitled section from its definitive Proxy Statement to be filed with the Securities and Exchange

Commission in connection with its 2013 Annual Meeting of Shareholders.

59
Item 13 - Certain Relationships and Related Transactions, and Director Independence

Effective January 1, 1990, John H. Alexander, an officer and director of the Company participated with a group of investors that

acquired the mineral and fee interest on one of the Company's oil and gas leases (Santa Fe Energy lease) in the Carneros Creek field after the

Company declined to participate. The thirty-three percent interest owned by Mr. Alexander represents a minority interest in the investor group.

Royalties on oil and gas production from this property paid to the investor group approximated $222,500 in 2012, $226,200 in 2011 and

$195,000 in 2010.

As a director, Mr. Alexander has abstained from voting on any of the above matters that have been brought before the Board of

Directors involving the Santa Fe lease.

Item 14. Principal Accounting Fees and Services

The Company hereby incorporates by reference the information contained under the section entitled ''Principal Accounting Fees and

Services'' or a similarly entitled section from its definitive Proxy Statement to be filed with the Securities and Exchange Commission in

connection with its 2013 Annual Meeting of Shareholders.

Item 15 - Exhibits and Financial Statement Schedules

3.1 Restated Articles of Incorporation of Pyramid Oil Company (previously filed by the registrant on December 17, 2009 as

Exhibit 3.1 to the registrant's Current Report on Form 8-K, and incorporated herein by reference).

3.2 Amended and Restated Bylaws of Pyramid Oil Company (previously filed by the registrant on December 17, 2009 as

Exhibit 3.2 to the registrant's Current Report on Form 8-K, and incorporated herein by reference).

10.1 Employment Agreement of John H. Alexander, dated February 21, 2002 (previously filed by the registrant on March 29,

2002 as Exhibit 10.4 to the registrant's Quarterly Report on Form 10-QSB, and incorporated herein by reference).

10.2 Severance Award Agreement of John H. Alexander, dated January 9, 2007 (previously filed by the registrant on January

16, 2007 as Exhibit 99.1 to the registrant’s Current Report on Form 8-K, and incorporated herein by reference).

10.3 Severance Award Agreement of John H. Alexander, dated December 30, 2008 (previously filed by the registrant on

January 6, 2008 as Exhibit 10.1 to the registrant’s Current Report on Form 8-K, and incorporated herein by reference).

10.4 Severance Award Agreement of John H. Alexander, dated June 4, 2009 (previously filed by the registrant on March 30,

2011 as Exhibit 10.4 to the registrant’s Annual Report on Form 10-K, and incorporated herein by reference).

10.5 Severance Award Agreement of John H. Alexander, dated September 21, 2010 (previously filed by the registrant on

November 12, 2010 as Exhibit 10.1 to the registrant’s Quarterly Report on Form 10-Q, and incorporated herein by

reference).

23.1 Consent of SingerLewak LLP.

23.2 Consent of MHA Petroleum Consultants, LLC.

60
31.1 Certification of Chief Executive Officer Pursuant to 15 U.S.C. Section 7241, as Adopted Pursuant to Section 302 of the

Sarbanes-Oxley Act of 2002.

31.2 Certification of Chief Financial Officer pursuant to 15 U.S.C. Section 7241, as adopted pursuant to Section 302 of the

Sarbanes-Oxley Act of 2002.

32.1 Certification of Chief Executive Officer pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the

Sarbanes-Oxley Act of 2002.

32.2 Certification of Chief Financial Officer pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the

Sarbanes-Oxley Act of 2002.

99.1 Report dated March 18, 2013 of MHA Petroleum Consultants, LLC, independent petroleum engineers.

101.0 The following financial information from the Annual Report on Form 10-K of Pyramid Oil Company for the year ended

December 31, 2012, formatted in XBRL (eXtensible Business Reporting Language): (1) Balance Sheets as of December

31, 2012 and December 31, 2011; (2) Statements of Operations for the years ended December 31, 2012, 2011 and 2010;

(3) Statements of Shareholders' Equity for the years ended December 31, 2012, 2011 and 2010; (4) Statements of Cash

Flows for the years ended December 31, 2012, 2011 and 2010; and (5) Notes to Financial Statements.*

* Pursuant to Rule 406T of Regulation S-T, the information in Exhibit 101 (a) is “furnished” and is not deemed to be

“filed” or part of a registration statement or prospectus for purposes of Section 11 or 12 of the Securities Act of 1933, as

amended, (b) is deemed not to be “filed” for purposes of Section 18 of the Securities Exchange Act of 1934, as amended,

and (c) is not otherwise subject to liability under those sections.

61
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.

PYRAMID OIL COMPANY

March 29, 2013 By: JOHN H. ALEXANDER

John H. Alexander

Director/President

Chief Executive Officer

Pursuant to the requirements of the Securities Exchange Act of 1934, this report has been signed below by the following persons on

behalf of the registrant and in the capacities and on the dates indicated.

JOHN H. ALEXANDER Director/President March 29, 2013

John H. Alexander Chief Executive Officer

MICHAEL D. HERMAN Director/Chairman of the Board March 29, 2013

Michael D. Herman

JOHN E. TURCO Director March 29, 2013

John E. Turco

GARY L. RONNING Director March 29, 2013

Gary L. Ronning

LEE G. CHRISTIANSON Corporate Secretary/ March 29, 2013

Lee G. Christianson Principal Accounting and

Financial Officer

62
Exhibit 23.1

Consent of Independent Registered Public Accounting Firm

We consent to the incorporation by reference in Registration Statement (No. 333-175706) on Form S-8 of Pyramid Oil Company of our report

dated March 29, 2013, relating to our audit of the financial statements which appear in this Annual Report on Form 10-K of Pyramid Oil

Company for the year ended December 31, 2012.

SingerLewak LLP

Los Angeles, California

March 29, 2013
EXHIBIT 23.2

March 26, 2013

Pyramid Oil Company

Attn: Mr. Lee Christianson

2008 21st Street

Bakersfield, California 93302

Dear Lee:

Below is our consent for the references to MHA Petroleum Consultants in the Form 10-K of the Annual Report of Pyramid Oil Company.

CONSENT OF INDEPENDENT PETROLEUM ENGINEERS

We hereby consent to the references to our firm, in the context in which they appear and to our oil and gas reserve estimates as of December

31, 2012, included in the Annual Report on Form 10-K of Pyramid Oil Company for the fiscal year ended December 31, 2012, as well as in

the notes to the financial statements included therein. We also hereby consent (1) to the incorporation by reference of the references to our

firm, in the context in which they appear, and to our reserve estimates as of December 31, 2012, into Pyramid Oil Company's filed

Registration Statement on Form S-8, and (2) to the filing of our report dated March 12, 2013 as an exhibit to the Annual Report on Form 10-

K of Pyramid Oil Company.

MHA PETROLEUM CONSULTANTS

Bakersfield, California

March 26, 2013

Very truly yours,

Alan A. Burzlaff, P.E.

President MHA California

4700 Stockdale Hwy, Suite 110 Bakersfield, CA 93309 USA Tele: 661-325-0038
Exhibit 31.1

Certification Pursuant to 15 U.S.C. Section 7241

As Adopted Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002

I, John H. Alexander, certify that:

1. I have reviewed this annual report on Form 10-K of Pyramid Oil Company;

2. Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to

make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period

covered by this report;

3. Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material

respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4. The registrant's other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined

in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and

15d-15(f))for the registrant and have:

a) Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our

supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others

within those entities, particularly during the period in which this report is being prepared;

b) Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed

under our supervision, 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;

c) Evaluated the effectiveness of the registrant's disclosure controls and procedures and presented in this report our conclusions about

the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

d) Disclosed in this report any change in the registrant's internal control over financial reporting that occurred during the registrant's

most recent fiscal quarter (the registrant's fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably

likely to materially affect, the registrant's internal control over financial reporting; and

5. The registrant's other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting,

to the registrant's auditors and the audit committee of the registrant's board of directors (or persons performing the equivalent functions):

a) All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are

reasonably likely to adversely affect the registrant's ability to record, process, summarize and report financial information; and

b) Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant's

internal control over financial reporting.

Dated: March 29, 2013

By: JOHN H. ALEXANDER

John H. Alexander

President and

Chief Executive Officer
Exhibit 31.2

Certification Pursuant to 15 U.S.C. Section 7241

As Adopted Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002

I, Lee G. Christianson, certify that:

1. I have reviewed this annual report on Form 10-K of Pyramid Oil Company;

2. Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to

make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period

covered by this report;

3. Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material

respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4. The registrant's other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined

in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and

15d-15(f)) for the registrant and have:

a) Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our

supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others

within those entities, particularly during the period in which this report is being prepared;

b) Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed

under our supervision, 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;

c) Evaluated the effectiveness of the registrant's disclosure controls and procedures and presented in this report our conclusions about

the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

d) Disclosed in this report any change in the registrant's internal control over financial reporting that occurred during the registrant's

most recent fiscal quarter (the registrant's fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably

likely to materially affect, the registrant's internal control over financial reporting; and

5. The registrant's other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting,

to the registrant's auditors and the audit committee of the registrant's board of directors (or persons performing the equivalent function):

a) All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are

reasonably likely to adversely affect the registrant's ability to record, process, summarize and report financial information; and

b) Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant's

internal control over financial reporting.

Dated: March 29, 2013

By: LEE G. CHRISTIANSON

Lee G. Christianson

Chief Financial Officer
Exhibit 32.1

Pyramid Oil Company

Certification Pursuant to 18 U.S.C. Section 1350

As Adopted Pursuant to Section 906

Of The Sarbanes-Oxley Act of 2002

In connection with the Annual Report of Pyramid Oil Company (the Company) on Form 10-K for the period ended December 31, 2012, as

filed with the Securities and Exchange Commission (the Report), I, John H. Alexander, Chief Executive Officer of the Company, certify,

pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, that, to my knowledge:

(1) The Report fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934; and

(2) The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of

the Company.

Dated: March 29, 2013

JOHN H. ALEXANDER

John H. Alexander

Chief Executive Officer
Exhibit 32.2

Pyramid Oil Company

Certification Pursuant to 18 U.S.C. Section 1350

As Adopted Pursuant to Section 906

Of The Sarbanes-Oxley Act of 2002

In connection with the Annual Report of Pyramid Oil Company (the Company) on Form 10-K for the period ended December 31, 2012, as

filed with the Securities and Exchange Commission (the Report), I, Lee G. Christianson, Chief Financial Officer of the Company, certify,

pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, that, to my knowledge:

(1) The Report fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934; and

(2) The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of

the Company.

Date: March 29, 2013

LEE G. CHRISTIANSON

Lee G. Christianson

Chief Financial Officer
EXHIBIT 99.1

PYRAMID OIL COMPANY

THIRD PARTY REPORT ON RESERVES

BY

MHA PETROLEUM CONSULTANTS

This report is provided to satisfy the requirements contained in Item 1202(a)(8) of the United States Securities and Exchange Commission

Regulation S-K.

The numbering of the items below corresponds to the requirements set out in Item 1202(a)(8) of Regulation S-K. The terms, defined in

Regulation S-K and Regulation S-X, have the same meaning in this report.

i. We prepared an independent evaluation of the proved oil and gas reserves of Pyramid Oil Company (Pyramid) for the management of

Pyramid. The primary purpose of our evaluation report was to provide estimates of reserves information in support of Pyramid’s yearend reserves reporting requirements under U.S. Securities Regulation S-K and for other internal business and financial needs of

Pyramid.

ii. We evaluated and reviewed the reserves of Pyramid as of December 31, 2012. The completion (transmittal) of our report was March

12, 2013.

iii. The following table presents the proved reserves, net after royalty, that we estimated using constant prices and costs, by geographic

area. Our report covers 100 percent of the total net proved oil and natural gas reserves of Pyramid.

Pyramid Net Proved Reserves

Location of Reserves

Crude

Oil

Mbbl

Natural

Gas

MMcf

Oil

Equivalent

1

Mbbl

State of California, USA

Portion of Total Covered

481.6

99.9%

0.0

0.0%

481.6

99.9%

State of New York, USA

Portion of Total Covered

0.0

0.0%

0.0

0.0%

0.0

0.0%

State of Texas, USA

Portion of Total Covered

0.3

0.1%

0.0

0.0%

0.3

0.1%

1Oil equivalence factors: Crude Oil = 1 bbl/bbl; Natural Gas = 6 mcf/bbl

4700 Stockdale Highway, Suite 110 , Bakersfield, CA 93309 * Phone: (661) 325-0038 Fax: (661) 325-4178
iv. We reviewed 100 percent of Pyramid’s reserves in connection with the preparation of this report. This report has been prepared in

accordance with our understanding of the Standards Pertaining to the Estimating and Auditing of Oil and Gas Reserve Information as

promulgated by the Societies of Petroleum Engineers and Petroleum Evaluation Engineers, and in our opinion, it will conform to the

U.S. Securities and Exchange Commission regulations and requirements.

Pyramid furnished us all of the accounts, records, recent production, estimated capital costs, operating expenses and other data required

for this evaluation. The ownership interest and other factual data provided by Pyramid were accepted without independent verification

(with the exception of oil and gas production data which were independently verified through the public websites of the respective

conservation departments of the states of California, New York & Texas).

We did not conduct site inspections of the properties presented in this report nor was it considered necessary for the purposes of our

report.

v. Proved oil and gas reserves are the estimated quantities of crude oil and natural gas which geological and engineering data demonstrate

with reasonable certainty to be recoverable in the future years from the known reservoirs under existing economic and operating

conditions. The oil and natural gas prices used in this report are based on a 12-month average price, calculated as the unweighted

arithmetic average of the first-of-the-month prices (or realized monthly prices) for the 12-month period of January to December, 2012.

Product prices that were actually used for each property reflect adjustment for gravity, quality, local conditions and/or distance from

market. Operating costs for the leases and wells in this report are based on the operating expense data provided by Pyramid and include

only those costs directly applicable to the leases and wells.

The production (reserves) forecast for each lease was based on historical production data provided by Pyramid or obtained from public

records through December 2012. The leases were evaluated using a decline curve analysis technique to determine the forecast of future

oil or gas production. For the California and New York leases, an exponential decline curve was found to provide a good match to the

historical production trend. The Texas lease exhibited a hyperbolic trend. There was no additional engineering or geological

information available to us with which to make any volumetric checks of the assigned gas reserves.

For the oil reserves, estimated future annual operating cost for each lease was based on the full year 2012 operating costs incurred or

paid by Pyramid (through December 2012). In some cases adjustments were made to exclude non-recurring costs from the calculation

of the projected monthly operating costs. Overhead expenses are not included in the economic analyses beyond those directly

attributable to the respective properties included in the operating costs provided by Pyramid.

MHA Petroleum Consultants

Reserves Report as of December 31, 2012

Pyramid Oil Company

Page 2
For the New York gas wells, there are no reserves in this year’s evaluation because the gas production is uneconomic at the current

SEC price. Operating costs for the New York gas properties were calculated using January - December 2012 expenses. The average

2012 SEC gas price was $2.63/mcf compared to $4.02/mcf for the 2011 SEC price. This is a 35 percent drop in natural gas price

which effectively renders all the New York gas wells uneconomic.

In our economic analysis, operating and capital costs are those costs estimated as applicable at the effective date of our report, with no

future escalation. The capital costs and revised operating costs associated with the implementation of committed future projects may be

included in the economic projections.

vi. Our report has been prepared assuming the continuation of existing regulatory and fiscal conditions subject to SEC regulations. There

is no assurance that changes in regulation will not occur; such changes, which cannot reliably be predicted, could impact Pyramid’s

ability to recover the estimated reserves.

vii. The reserves and economics indicated in this report are estimates only and should not be considered as exact quantities. They represent

our best judgments, after having utilized generally accepted engineering and economic procedures. Moreover, the net revenues

indicated herein should not be construed as fair market values. The accuracy of reserve evaluations is always subject to uncertainty.

The magnitude of this uncertainty is generally proportional to the quantity and quality of data available for analysis. As reservoirs

mature and new information becomes available, revisions may be required which may increase or decrease the previous reserve

assignments.

The reserves contained in this report are based on a reserve audit, which utilized a technical analysis of the available data using

accepted petroleum engineering principles. However, they must be accepted with the understanding that further information and future

reservoir performance after the date of the estimate may justify their revision.

viii. In our opinion, the reserves information we evaluated has been determined in accordance with all appropriate industry standards,

methods and procedures applicable for the filing of reserves information under U.S. SEC Regulation S-K.

ix. A summary of our conclusions with respect to the Pyramid reserves estimates is provided below:

MHA Petroleum Consultants

Reserves Report as of December 31, 2012

Pyramid Oil Company

Page 3
Proved Developed Proved Total

Producing

(PDP)

Non-Producing

(PDNP)

Undeveloped

(PUD)

Proved

(P1)

Oil Reserves, Thousand (M) Barrels

Gross (8/8ths)

Net Revenue Interest

611.3

455.2

35.6

26.7

0.0

0.0

646.9

481.9

Gas Reserves, MMcf

Gross (8/8ths)

Net Revenue Interest

0.0

0.0

0.0

0.0

0.0

0.0

0.0

0.0

Future Revenue, Thousand (M) $ 48,122.0 2,882.0 0.0 51,004.1

Future Deductions, M $ 24,899.1 1,041.9 0.0 25,941.0

Future Net Income, M $

Undiscounted

Discounted @ 10 percent

23,223.0

13,787.3

1,840.2

713.1

0.0

0.0

25,063.2

14,500.4

Prepared by:

MHA Petroleum Consultants

Bakersfield, California

March 22, 2013

Alan A. Burzlaff, P.E.

President MHA California

Licensed by the California Board for

Professional Engineers and Land Surveyors

License No. P 1386

MHA Petroleum Consultants

Reserves Report as of December 31, 2012

Pyramid Oil Company

Page 4