8-K

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

FORM 8-K

CURRENT REPORT

Pursuant to Section 13 or 15(d) of the

Securities Exchange Act of 1934

Date of Report (Date of Earliest Event Reported):  April 21, 2010 (April 21, 2010)

BEST ENERGY SERVICES, INC.

(Exact name of registrant as specified in its charter)

Nevada	000-53260	02-0789714
(State or Other Jurisdiction of Incorporation)	(Commission File Number)	(I.R.S. Employer Identification Number)

5433 Westheimer Road; Suite 825 Houston, Texas	77056
(Address of principal executive offices)	(Zip Code)

 (713) 933-2600

(Registrant’s telephone number,

including area code)

_________________________________

(Former name or former address, if changed since last report.)

Check the appropriate box below if the Form 8-K filing is intended to simultaneously satisfy the filing obligations of the registrant under any of the following provisions (see General Instruction A.2. below):

o Written communications pursuant to Rule 425 under the Securities Act (17 CFR 230.425)

o Soliciting material pursuant to Rule 14a-12 under the Exchange Act (17 CFR 240.14a-12)

o Pre-commencement communications pursuant to Rule 14d-2(b) under the Exchange Act (17 CFR 240.14d-2(b))

o Pre-commencement communications pursuant to Rule 13e-4(c) under the Exchange Act (17 CFR 240-13e-4(c))

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Item 7.01 Regulation FD Disclosure

From time to time, senior management of Best Energy Services, Inc. (the “Company”) meets with groups of investors and/or business analysts.  The slide presentation attached hereto as Exhibit 99.1 (the “Presentation”) has been prepared and will be made at the Accredited Members Spring Small/Microcap Conference on April 21, 2010.

Statements contained in the Presentation that state management’s expectations and assumptions as to future events are forward-looking statements intended to be covered by the safe harbor provisions of the Private Securities Litigation Reform Act of 1995.  Investors should note that actual results could differ materially from those projected or assumed in such forward-looking statements.  Factors that could affect such results include, among other things, those mentioned in the Company’s annual report on Form 10-K/A for the transition period ended December 31, 2008 and quarterly reports on Form 10-Q for the quarters ended March 31, June 30 and September 30, 2009, all of which have been filed with the Securities and Exchange Commission.

The information being furnished in this report shall not be deemed to be “filed” for purposes of Section 18 of the Securities Exchange Act of 1934, as amended (the “Exchange Act”), or otherwise subject to the liabilities of that section and is not deemed to be incorporated by reference into any filings made under the Securities Act of 1933, as amended, or the Exchange Act.

Item 9.01. Financial Statements and Exhibits

(a) Exhibits

99. 1     Slide Presentation prepared for the Accredited Members Spring Small/Microcap Conference to occur on April 21, 2010.

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SIGNATURE

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

Dated: April 21, 2010

BEST ENERGY SERVICES, INC.
By:	/s/ Mark G. Harrington
	Mark G. Harrington
	Chief Executive Officer

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EXHIBIT INDEX

Exhibit No. Description

99. 1 Slide Presentation prepared for the Accredited Members Spring Small/Microcap Conference to occur on April 21, 2010.

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EX-99.1

Exhibit 99.1

Presented to

Accredited Members
Conference

April 21, 2010

Certain statements contained in this presentation, which are not based on historical facts, are forward-
looking statements as the term is defined in the Private Securities Litigation Reform Act of 1995 and, as
such, are subject to substantial uncertainties and risks that may cause actual results to materially differ
from projections. Although the Company believes that the expectations expressed herein are based on
reasonable assumptions within the bounds of the Company’s knowledge of its businesses, operations,
business plans, budgets and internal financial projections, there can be no assurance that actual results
will not differ materially from the expectations expressed herein. Important factors currently known to
management that could cause actual results to differ materially from those in forward-looking statements
include the Company's ability to (i) properly execute its business model, (ii) raise additional capital to
sustain its business model, (iii) attract and retain personnel, including highly qualified executives,
management and operational personnel, (iv) negotiate favorable current debt and future capital raises,
(v) manage the inherent risks associated with operating a diversified business to achieve and maintain
positive cash flow and net profitability, and (vi) get back into compliance, and remain in compliance, with
its current senior secured credit facility with PNC Bank, N.A. as well as the other risks detailed from time
to time in the SEC reports of Best Energy Services, Inc., including its annual report on Form 10-K/A for the
transition period from February 1, 2008 to December 31, 2008 and its quarterly reports on Form 10-Q for
the three months ended March 31, 2009, June 30, 2009 and September 30, 2009. In light of these risks
and uncertainties, there can be no assurance that the forward-looking information contained in this
presentation will, in fact, occur.  The forward-looking statements made herein speak only as of the date
hereof and Best Energy disclaims any obligation to update these forward-looking statements.

OUR VISION:

We are building our business in two complementary directions:

§By continuing to provide a single point source for all our customer’s
needs:

üSuperior Safety Record

üValue Pricing in All Markets

üA long history of Performance

üAnd Soon - Capital.

§By expanding our area:

üUsing our Customer-Centric approach

üMoving into other basins where legacy companies and
their practices invite our competitive presence.

OUR VISION:

OUR HISTORY:

§Q1 2008-- Formed with Three Acquisitions

üBest Well Services (established in 1991)

üBob Beeman Drilling

üCertain Housing Accommodation assets

§Q42008-- BoardMandated Management Changes

üAnticipated significant commodity price and
activity decline

üDiscontinued rig redeployment model

üCut annual G&Afrom$ 5.4MM to $960K

üImplemented new profit models, to gauge business
unit viability

§Q4 2009-- Discontinued Drilling and Housing business units

§Q12010--Established Customer-Centric Growth Model

Our Leadership: Accomplished & Respected

Mark Harrington, Chairman and CEO

•Founding board member; Appointed CEO December 2008

•30 years experience - Oil & Gas Exploration, Development and
Finance

•Prior Chairman/President - Seven, Energy and Private Equity
Companies

•Featured on CNBC, Canada AM, Dow Jones News & Bloomberg

Eugene Allen, President and COO

•A second generation oilman with 4o years hand-on experience in
the oil and gas industry.

• 16 Years at Best Well Services.

•Prior Experience: Pool Well Service, Pride Petroleum and KMA
Well Service

•Executing the operations of BWS and orderly liquidation of non-
strategic assets from discontinued business units.

Our Platform

Current Operations: Hugoton Basin

Rife with Opportunity

Ø24 Trillion Cubic Feet Produced since 1930

Ø 12 Trillion Cubic Feet Remaining to be Produced

Ø 12,000+ Active Wells in the Basin

Ø 50+ Active Operators

Our Strengths Define Who We Are

ØLongevity - BWS established in 1991

ØSustainability - Grew steadily from 1 rig to 25 rigs

Ø Reputation - A coveted book of business

ØCustomer Centric - A history of value pricing and service to
our customers

ØManagement - Significant depth of management and
continuity of key employees

Why Our Customers Choose Best

Ø“Safety First”

•An Exceptional Safety Record - well over a year, with no lost time due to a
safety incident

• Rank at the highest level among our customer’s providers

ØValue Pricing- always Fair and Competitive

•Market Peak:BWS $240/hourCompetitors $360/hour

•Today’s Pricing:BWS $210/hourCompetitors $240/hour

ØReputation and Performance

• Continuity in our Crews- Historical turnover <5%, industry norm >40%

• Superior Depth of Knowledge and Experience- Faster execution times
for our customers

Ø Soon to Come: A delivery mechanism for our customers’ greatest need- Capital.

The Results : Success in Growth Market Share

Our Customers Include:

Anadarko	Dominion	Linn Energy	Oxy USA
Arena	Ellora Energy	Marlin Oil	Pioneer
Bengalia L&C	Enervest	Merit Energy	Pride Energy
Cleary	EOG	Midwestern	Samson
Devon	Kaiser-Francis	Noble	XTO

Building on Our Platform

•Hugoton Basin Financing Partners

•Basin-Specific Scaling

Hugoton Basin Financing Partners:

A Compelling Financing Option for Our Customers

ØShut-in wells Financially Damage the Customer

•No cash flow to support area G&A

•Reduces Borrowing Base through Absent Cash Flow and Degradation of
Reserve Category

Ø HBFP allows Customers to Focus Capital Allocations on Highest Impact
Areas:

•Gulf of Mexico

•Shale plays

•International

Ø Earn-In structure is Bank Friendly for the Customer

•No bank capital required

•No sub or senior debt taken-on

•No inter-creditor agreements

•Not a sale of a liened property

•Enhances Credit Quality by increasing Operators cash flow

Ø Customer Retains Operations and Cash Flows to Support Regional G&A

Institutional

Investor

$5 Million
Commitment

Hugoton Basin

Financing Partners

Best’s
Customers

Rejuvenated Wells

Preferred Cash

Recoupment +

Premium

$ For

Rejuvenation

BEST

Work Contract

Paymentfor

Services

Share in
Fund’s

Production

Warrants

Negotiated
Back- in APO

Cash Flow

100% Cash Flow
After HBFP Payback

HBFP: A First Of Its Kind Financing Product

Created by a Former Customer - - Best’s CEO

HBFP Has Connected the Dots

ØOperators Gain Access to Much Needed Capital

•Unavailable from Corporate Allocation

•Unavailable from Lenders/Capital Markets

Ø Institutional Investor Gains High Quality and Closable
Deal Flow

•Earn-in Structure Obviates Disconnect in Buyer/
Seller Expectations

•Best’s leading position in the Hugoton makes us the
Preeminent Intelligence Network for Accessing
Candidates

Basin-Specific Scaling: What We Look For

—Low per unit F & D costs

—Rising activity level

—Connective Customer Entrée

—Competitor pricing invites our Presence

Report Card on First Target:

South Texas Eagle Ford Shale

üLow F & D Costs - Economics Maintained to $3/Mcf gas

IRR on Type Well - - Varied Natural Gas Pricing ($/Mcf)
Shale Play	$3.00/Mcf	$4.00/Mcf	$5.00/Mcf
Eagle Ford Shale	25-35%	45-60%	65-90%
Barnett Shale	0%	0-10%	5-15%
Fayetteville	5%	15%	25%
Haynesville	9%	28%	51%
Marcellus	18%	35%	54%
Source: various trade publications and company data

Report Card on First Target:

South Texas Eagle Ford Shale

PRising Activity Level - Permits up 40% over 2009

üConnective Customer Entrée - Long-standing
Hugoton Basin Customers hold 500,000+acres in
the play

PCompetitor Pricing Invites our Entry - Their prices
are at a 30% premium to Best

Financial Considerations

•ScalingRevenue

•Deleveraging

•Financial Performance Drivers

•Rig Count Break Points

•Annualized Upside Scenarios

•Share Capitalization

•Investment Consideration

Scaling Revenue - - A Work in Progress

ØSTEP ONE: Capture Existing Market Share (Initiated Q1 2009)

•Accomplished

üNow at 80%+ vs. 38% in 2008

ØSTEP TWO: Capture New Projects (Secured Q4 2009)

•Accomplished

üAwarded coveted 6 rig contract from major oil company

üCredited to safety record and historical performance for customer

ØSTEP THREE: Game-changing revenue creation model (Q1 2010)

•Hugoton Basin Financing Partners

üMarket Potential-- $20MM+ annually

üMarries proprietary financial product to asset base

• Redeploy/Add/Scale into other Basins

üValue Pricing model= Pricing Power

ü Customer Connectivity

Deleveraging

ØTerm Debt level is too high at $16.8 million

ØThough terms are favorable

•LIBOR +4%

•Amortizes $1.5mm over next 12 months

ØNon-Dilutive Solutions:

• Sale of equipment from discontinued operations

•Target $4MM in next 120 days

• $1.2MM sold to date

• Periodic Sales of“Production Tails” from HBFP

• Ramp-up in free cash flows

Financial Drivers

ØOperating and Overhead Expense Containment Completed

•G&A to remain <$1mm/year

•Very nominal increase to indirect costs

ØThree Revenue Drivers For 2010-2012

•Market Conditions in Hugoton

o Natural gas prices at wellhead

o Capital Allocations by customers

o Potential impact from HBFP product

•Scaling of HBFP

o Rig activity in Hugoton

o Rig activities in other basins

o Bundled services

•Expansions into other Basins

o Customers welcome value-pricing, reputation and
performance

Rig Count Break Points:

•Positive EBITDA10 Rigs

•1:1 coverage on debt service- 15 Rigs

•AnnualEBITDA $3.2MM+- 20 Rigs

•Annual EBITDA $5.0MM+- 25Rigs

•Annual EBITDA $8.5MM+- 35 Rigs

Note:

•12 Rigs running as of April 2010

•Figures exclude added revenues from HBFP

Annualized Upside Scenarios

	20-Rig Case	25-Rig Case	35-Rig Case
Revenue	$  11,900	$  15,600	$ 23,000
Expenses (Direct and Indirect)	$   7,740	$   9,640	$13,570
Operating Income	$   4,160	$   5,960	$  9,430
Corporate G&A	$     960	$      960	$     960
EBITDA	$  3,200	$   5,000	$  8,470
Interest (Cash & Non-Cash)	$  1,076	$    1,076	$   1,076
Depreciation	$  1,724	$    1,724	$   2,224
Net Income	$    400	$    2,200	$    5,170

Share Capitalization: Treasury Method Dilution

As of4/1/2010*
Current shares issued	35,544,409
Undiluted shares after offering	35,544,409
Total dilution at $0.25	56,780,184
Total dilution at $0.50	70,730,084
Total dilution at $0.75	75,546,724
Fully diluted	89,505,877

*post equity offering

Investment Considerations

ØSuccessful Turn-around Executed by New Management

•G&A reduced from $5.4MM in 2008 to less than $960,000

•Discontinued 3 of 4 unprofitable linesof business

•EBITDA positive beginning Q1 2010

ØSound Fundamentals in Hugoton Basin

•Largest conventional natural gas basin in U.S.

•12,000+ active wells

•12 TCF of gas left to be produced

ØExcellent Business Platform in Workover Services

•50%+ gross margins

•Unblemished 19 year reputation

•Strong continuity of management

•Low employee turnover <5% vs industry norm of 45%

•First in class safety record

•History of value pricing to customers—up markets and down

ØDoubled Market Share in Core Business In Down
Market

•80% share vs. 35% two years ago

•Demonstrated reputational and pricing prowess of BWS

•Coveted Book of Business Expanding

ØA “Customer-Centric” Approach

•Safety first

•Value pricing

•Performance and reputation

•Soon to come—capital delivery to the customers

ØTwo Potentially Significant Growth Engines

•Hugoton Basin Financing Partners

oFirst of its kind financing

oConnects the Dots between Customer Capital Needs and
Financing

oCustomer friendly and customer fair

•Basin- Specific Scaling

oValue pricing = pricing power

oActive growth in shale gas in target basin

ØSignificant Upside on Execution

—Positive EBITDA at 10 rig count

—Positive net income at 20 rig count

—Potential on successful HBFP execution

—Scalability of HBFP to other basins

—Potential deployment in Eagle Ford Basin

ØA Firmly Committed Management Team

—CEO signed on to 3 year contract

—Interests fully aligned with shareholders

—Significant option positions for ALL key employees

—2/3 of options vest only on hitting $5MM EBITDA-- full 25 rig
deployment for 1 year

Corporate Headquarters

5433 Westheimer Avenue, Suite 825

Houston, Texas 77056

Phone: 713-933-2600