8-K

UNITED STATES
SECURITIES AND EXCHANGE COMMISSION

Washington, DC 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):
February 7, 2005

PETROQUEST ENERGY, INC.

(Exact name of registrant as specified in its charter)

DELAWARE	72-1440714
(State of Incorporation)	(I.R.S. Employer Identification No.)
400 E. Kaliste Saloom Rd., Suite 6000
Lafayette, Louisiana	70508
(Address of principal executive offices)	(Zip code)

Commission File Number: 0-019020

Registrant’s telephone number, including area code: (337) 232-7028

     Check the appropriate box below if the Form 8-K filing is intended to simultaneously satisfy the filing obligation of the registrant under any of the following provisions:

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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TABLE OF CONTENTS

	Item 7.01 Regulation FD Disclosure
	Item 9.01 Financial Statements and Exhibits
SIGNATURE
INDEX TO EXHIBITS
Presentation dated February 7, 2005

Item 7.01 Regulation FD Disclosure

     On February 7, 2005, representatives of PetroQuest Energy, Inc. (the “Company”) intend to make a presentation at the Independent Petroleum Association of America’s (“IPAA”) Oil and Gas Symposium Small Cap Conference in Palm Beach, Florida at 9:10 a.m. Eastern time. We are filing herewith a copy of the presentation as exhibit 99.1. Beginning at 9:10 a.m. Eastern time on Monday, February 7, 2005, a webcast of the presentation will be made available through a link on our website at www.petroquest.com.

     In accordance with General Instructions B.2 and B.6 of Form 8-K, the foregoing information, including Exhibit 99.1, shall not be deemed “filed” for the purposes of Section 18 of the Securities Exchange Act of 1934 or otherwise subject to the liabilities of that section, nor shall such information and Exhibit be deemed incorporated by reference in any filing under the Securities Act of 1933 or the Exchange Act, except as shall be expressly set forth by specific reference in such a filing.

Item 9.01 Financial Statements and Exhibits

     (c) Exhibits:

99.1   Presentation dated February 7, 2005.

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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 thereunto duly authorized.

	PETROQUEST ENERGY, INC.
Date: February 7, 2005	By:	/s/ Daniel G. Fournerat
		Daniel G. Fournerat
		Senior Vice President, General Counsel and Secretary

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INDEX TO EXHIBITS

EXHIBIT
NUMBER	DESCRIPTION
99.1	Presentation dated February 7, 2005.

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EX-99.1

February 7, 2005 IPAA Small Cap Oil & Gas Investment Symposium

Company Strategy Focus in Gulf Coast Basin (onshore and Gulf of Mexico Shelf), East Texas and Arkoma Basin Goal to maintain 60% of reserves in long lived basins while maintaining 75% of production from Gulf Coast region (45% of reserves long-lived at 12/31/04) Balanced growth approach Moderate/low risk exploitation/development Acquisitions High impact exploration Manage risk by spreading exposure in more projects 50% average WI in Gulf Coast 70% average WI in long lived basins Operate major projects Maintain financial flexibility

Why Invest in PetroQuest? Impressive growth since going public in September 1998 43% production CAGR 40% reserve CAGR Significant presence in three diverse basins - staged for growth in all three Small-cap stock with high liquidity Market capitalization - $225MM 12-month average daily volume - 500,000+ shares 97% drilling success rate during 2004 PQUE operates majority of its reserves Experienced and committed management team Significant intellectual capital in technical staff Insiders own approximately 20% of PQUE equity Exploration upside in proven basins

Production - Commodity Mix Oil Gas 27% 73% 43% - 6 Yr CAGR

Reserves - Category Mix Oil Gas 40% - 6 Yr CAGR

Production and Reserves - Basin Mix Production Reserves Gulf Coast E. Texas/Arkoma 25 % 75%

Drilling Activity 2000 2001 2002 2003 2004 2005 Net Wells 3.35 7.41 7.01 4.71 18.9 42.1 Gross Wells 8 13 10 10 33 74

Estimated Net Unrisked Reserve Potential

Lafayette Houston New Orleans Major Project Locations Non-operated PQUE operated 24 Producing Fields 238 Producing Wells Arkoma Basin East Texas Gulf Coast Region

2005 Drilling Schedule Drill Completion & Platform/Pipeline Construction Productive Well

2005 South Louisiana Drilling Program 2005 South Louisiana Drilling Program Oakbourne File/Gumbo Bisque (Completing) Cayenne Cracklin' (Drilling) Lafayette Southern Trace English Turn Le Triomphe

2005 South Louisiana Drilling Program

2005 Gulf of Mexico Drilling Program Shiraz "C" & Syrah Lafayette Spanish Bay Pebble Beach Pinehurst Sawgrass Spyglass Scottsdale

2005 Gulf of Mexico Drilling Program

Ship Shoal 72 Field Potential Developmental and Mid-Depth Exploitation Projects: Shiraz Zinfandel Sangria Dolcetto North Net Unrisked Reserve Potential 43 Bcfe "Deep Shelf" Opportunities: Syrah Pinot Noir Pinot Blanc Net Unrisked Reserve Potential 90 Bcfe PQUE Drills: 1. Merlot 2. Chardonnay 3. Cabernet 4. Sauvignon Blanc 5. Chenin Blanc 6. Chardonnay Acceleration 7. Burgundy 8. Bordeaux 9. Port 10. Beaujolais 11. Pinot Grigio 12. Riesling 13. Dolcetto 14. Chianti 15. Shiraz "B" Salt Dome Deep Shelf Opportunities Deep Shelf Opportunities 8,000' 14,000' 18,000' Syrah Prospect Pinot Noir Prospect

East Texas Basin 6 MMcfe/day net production 5,500 Mcfe/day net production in SE Carthage Field 500 Mcfe/day net production in the Barnett Shale 41,600 gross acres (16,500 acres developed) Travis Peak and Cotton Valley Formations $800,000 average well cost 600 - 1,200 MMcfe reserve potential per well Four year defined drilling inventory with additional upside in probable and possible reserves 10-12 wells to be drilled during 2005

Southeast Carthage Field Development LOUISIANA TEXAS LEGEND 2005 Drilling Program Locations PQUE Drills P-DP P-UD P-BP PQUE LEASE POSITION P-NP

Over 12,000 net acres Interest in 69 sections; operational control of 31 sections Currently 160-acre spacing Immediate gas production with little water 2,000 to 3,000' TVD, with 2,500' horizontal leg Typical economics: .7 Bcf; $350,000 completed well cost; 150-200 Mcf/day I.P. rate Additional producing horizons: Savanna Sand - 500' to 1,000' Cromwell Sand - 5,500' to 6,000' Booch Sand - 1,000' to 1,500' Operate 30+ miles of gathering system Current production of 2,500 Mcfe/day; increasing monthly Four year drilling inventory Oklahoma Arkansas Arkoma Basin PITTSBURG COUNTY Hartshorne Coal Arkoma Basin

Arkoma Basin LEGEND 2005 Locations Planned Post 2005 Locations Producing Wells PQUE Acreage PUD Location - Acquired Pipeline Connection Producing Sand Wells Vertical Hartshorne Coal Well Horizontal Hartshorne Coal Well Existing PQUE Gathering System Major Pipeline System

Hartshorne Coal - Vertical vs. Horizontal Horizontal wells produce 200-300% higher rate and 200-300% more reserves than vertical wells Horizontal wells require less capital and ultimately lower operating costs - with fewer wells needed per section

2005 Drilling Capital Program Project Focus Area Focus In $ millions Exploration $26.5 Development $48.5 Offshore $30.0 Onshore $21.0 E. Texas, Arkoma Basin $24.0

Financial Flexibility 1999 2000 2001 2002 2003 Debt/Mcfe 0.17 0.3 0.41 0.13 0.33 Credit Statistics at 9/30/2004 Senior Bank Credit Facility Borrowing Base $25 Million Outstanding Debt $9 Million Subordinated Term Credit Facility Total Credit Facility $20 Million Outstanding Debt $12 Million Debt/Book Capitalization 16% Debt/Market Capitalization 9% Debt/Mcfe

Revenue 2000 2001 2002 2003 9-mo. 2004 Revenue 22561 55342 48238 48688 62084

Gross Margin and Gross Margin Per Mcfe 2000 2001 2002 2003 9mo. 2004 Gross Margin/Mcfe 3.74 3.39 2.81 3.88 4.81 2000 2001 2002 2003 9-mo. 2004 Gross Margin/Mcfe 18492 46699 37539 37577 51327 Gross Margin Per Mcfe Gross Margin 2000 2001 2002 2003 9-mo. 2004 Gross Margin/Mcfe 3.74 3.39 2.81 3.88 4.81 2000 2001 2002 2003 9-mo. 2004 Gross Margin/Mcfe 18492 46699 37539 37577 51327

Reserve Life Index (TTM) 1999 2000 2001 2002 2003 Reserve Life 8.2 9.9 5.9 5.2 8.6

Summary Multi-basin focus with majority long-lived reserves and healthy cash flow from Gulf Coast Region Proven management and technical team - average 25+ years experience Extensive 3-D database which provides foundation for continued prospect generation Extensive prospect inventory with NET unrisked reserve potential of 350+ Bcfe - providing a 2 year drilling inventory in the Gulf Coast; a 4 year drilling inventory in our long-lived basins

February 7, 2005 The information presented herein may contain predictions, estimates and other forward- looking statements within the meaning of Section 27A of the Securities Act of 1933 and Section 21E of the Securities Exchange Act of 1934. Although the company believes that its expectations are based on reasonable assumptions, it can give no assurance that its goals will be achieved. Important factors that could cause actual results to differ materially from those included in the forward looking statements include the timing and extent of changes in commodity prices for oil and gas, the need to develop and replace reserves, environmental risks, drilling and operating risks, risks related to exploration and development, uncertainties about the estimates of reserves, competition, government regulation and the ability of the company to meet its stated business goals. IPAA Small Cap Oil & Gas Investment Symposium