Table of Contents

 
 
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): September 8, 2005
HELMERICH & PAYNE, INC.
(Exact name of registrant as specified in its charter)
State of Incorporation: Delaware
COMMISSION FILE NUMBER 1-4221
Internal Revenue Service – Employer Identification No. 73-0679879
1437 South Boulder Avenue, Suite 1400, Tulsa, Oklahoma 74119
(918)742-5531
 
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 (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))
 
 

 

TABLE OF CONTENTS

ITEM 7.01 REGULATION FD DISCLOSURE
ITEM 9.01 FINANCIAL STATEMENTS AND EXHIBITS
SIGNATURES
EXHIBIT INDEX
Slide Presentation

Table of Contents

ITEM 7.01 REGULATION FD DISCLOSURE
     Helmerich & Payne, Inc. will deliver an investor and securities analyst presentation that includes the slides filed as Exhibit 99.1 to this Current Report on Form 8-K, which are incorporated herein by reference.
     This information is not “filed” for the purposes of Section 18 of the Securities Exchange Act of 1934, as amended, and is not incorporated by reference into any filing made pursuant to the Securities Act of 1933, as amended, or the Securities Exchange Act of 1934, as amended. The furnishing of these slides is not intended to constitute a representation that such information is required by Regulation FD or that the materials they contain include material information that is not otherwise publicly available.
ITEM 9.01 FINANCIAL STATEMENTS AND EXHIBITS
     
Exhibit No.   Description
99.1
  Slides to be shown during an investor and securities analyst presentation.
SIGNATURES
     Pursuant to the requirements of the Securities Exchange Act of 1934, the Registrant has duly authorized the undersigned to sign this report on its behalf.
     
 
  HELMERICH & PAYNE, INC.
 
  (Registrant)
 
   
 
  /S/ Steven R. Mackey
 
   
 
  Steven R. Mackey
 
  Vice President
 
   
 
  DATE: September 8, 2005
EXHIBIT INDEX
     
Exhibit No.   Description
99.1
  Slides to be shown during an investor and securities analyst presentation.

 

 

Exhibit 99.1
Helmerich "&"#038; Payne, Inc. Lehman Brothers 2005 CEO Energy/Power Conference September 8, 2005 NYSE Stock Symbol: HP Common Dividend: $0.33 Average Basic Shares Outstanding: 51 Million Internet Address: www.hpinc.com Investor Relations Contacts: Doug Fears, CFO 918.588.5208 doug.fears@hpinc.com Juan Pablo Tardio, Manager, Investor Relations 918.588.5383 juanpablo.tardio@hpinc.com

 

The information contained within this presentation is forward looking and involves risks and uncertainties that could significantly impact expected results. A discussion of these risks and uncertainties is contained in the Company's Form 10-K filed with the Securities and Exchange Commission on December 13, 2004.

 

Potential for an up cycle that is prolonged and less volatile. First up cycle for H"&"#038;P as a pure play driller. 25 new FlexRigs scheduled for construction. Increase in rig fleet of 72% from 2000 to 2006. 50 new FlexRigs have established the new performance standard for the industry. What Is Different About This Cycle

 

International Platform Conventional FlexRigs Rig Fleet 27 11 28 62 The Three Distinct Markets Of H&P’s Rig Fleet 128 Total Rigs September 2005

 

The Three Distinct Markets Of H"&"P’s Rig Fleet International 27 US Land 90 Conventional 28 Mobile FlexRigs 87 153 Total Rigs September 2006

 

H"&"#038;P Rig 201 on Customer's Platform Before and After Hurricane Katrina

 

What is so distinctive about the FlexRig?

 

FlexRigs Strategically Positioned "&"#060; 6,000' 6,001' - 18,000' 18,001' - 20,000' "&"#062; 20,000' 1% 1% 25% 1% 3% 8% 88% 73% Well Depth Source: Smith International, Inc. May 1992 through May 2005 Active U.S. Land Drilling Rigs

 

Leader in New Ideas "&"#038; Applied Technology Integrated Top Drive Mechanized Tubular Handling VFD AC Drawworks BOP Handling V-ICIS eD Controls Communications

 

H“&”#038;P’s Organizational Support Structure

 

FY1997 1998 1999 2000 2001 2002 2003 2004 2005 2006E 18 - 25,000'+ 15 15 15 16 18 22 22 21 20 20 8 - 18,000' (Mobile "&"#038; FlexRigs 1, 2 "&"#038; 3) 15 21 25 23 31 44 61 69 70 73 6 - 12,000' (FlexRig4) 22 Move from Deep to Mid-Depth Land Rigs

 

U.S. Land Cash Flow Margin

 

FlexRig3 Project Return Estimates Baseline FlexRig4 ROIC Annualized FlexRig3 ROIC

 

Technology and Quality Service Make a Difference

 

Source: Thomson Financial August 3, 2005 EPS "&"#038; CFPS - Street Estimates

 

New Build Inflection Point: How did we get here? Where are we going? The line of demarcation.

 

EPS Sensitivity * .88 25 FlexRigs Working A Full Year Announced New Builds .36 $1000 Average Margin Per Rig Day Increase Annual EPS Increases US Land * Using 3Q05 Earnings "&"#038; Statistics As Baseline See Forward Looking Statement Disclaimer - Page 2

 

 

101 U.S. Rigs 27 International Rigs 128 Total H"&"#038;P Rigs 25 U.S. Construction 3 Management Contracts Rig Locations South America Venezuela 9/12 Colombia 2/2 Ecuador 8/8 Bolivia 1/1 Argentina 2/2 Chile 1/1 GOM 7/11 U.S. Land 87/90 California Equatorial Guinea

 

Rig Status as of 1 September 2005 Rigs Available 62 28 11 27 128 Rigs Working/ Contracted 62 25 8 24 119 % Activity 100% 89% 73% 89% 93% U.S. Land, FlexRig "&"#038; Mobile U.S. Land, Conventional U.S. Platform International Land Total Management Contracts: U.S. GOM "&"#038; CA Equatorial Guinea Total Rigs Working/Contracted 2 1 122

 

Segment Outlook - U.S. Land Sustained rig demand Potential for continuing dayrate increases Potential for additional term contracts New rig construction Growing customer focus on safety and performance Strong and Improving!

 

New Build Program 22 FlexRig4s and 3 FlexRig3 new-builds Expect outstanding financial returns Strong validation for FlexRig value proposition Operator benefits: Significant total drilling costs savings Accelerated well delivery and production Enhanced safety and environmental sensitivity

 

Increasing platform rig demand and supply Operating leverage available for potential recovery Rig management contract opportunities Segment Outlook - Offshore, U.S. GOM Steady, Good Potential

 

Venezuela - 9 rigs are working. 3 rigs available with strong prospects. Colombia - Both rigs working. Should continue for FY05. Ecuador - All eight rigs working. Strong market. Bolivia/Argentina - All four committed. Chile - New contract. Segment Outlook - International Recovering! Highest Activity in S. America since 1998

 

Innovative technology Reduced move times Reliability Drilling performance H"&"#038;P is the Leader in Field Performance

 

H"&"#038;P Land Rig Moves 1998 to 2004 1200 HP Mobile Rigs 1500 HP FlexRigs 1000 HP 1500 HP 2000 HP 3000 HP Average Rig Move Days 2.39 3.31 5.75 7.27 8.27 10.38 # moves 723 1150 266 158 130 89 Conventional Rigs (Rig move time: Time from rig release on last well to spud of next well including time to rig down, transport, rig up and prepare to spud.)

 

June 2002 - July 2005 H"&"#038;P FlexRig3 Downtime Performance

 

FlexRig3 Highlights of Rigs 210 - 241 1. Field Performance vs. customer's planned drill curves ? 838 complete wells as of 1 September 2005 ? 485 wells (65%) under ? 31 wells (4%) on ? 227 wells (31%) over 2. 53% of FlexRig3s are currently drilling directional, more technically difficult wells.

 

Example of Best Value: H"&"#038;P 213 FlexRig3 Example of Best Value: H"&"#038;P 213 FlexRig3 East Texas

 

Best Value - Reduced Well Cycle Time Estimated Field H"&"#038;P R213 1. Average Sep 05 Drilling days 13 7.7 Completion days 2 2 Moving days 5 3 Well cycle in days 20 12.7 2. Contractor rate/day $16,500 $20,500 Operator's other intangible cost per day estimate $9,500 $9,500 Operator's daily "spread" cost estimate $26,000 $30,000 Intangible cost per well $520,000 $381,000 3. Total Well Savings - per well $139,000 per year $4.0MM 4. Value captured by H"&"#038;P - per year $1.5MM

 

Best Value Reduced Well Cycle Time 3. Added value from FlexRig3 operations Lowest total well cost Increased wells per rig per year: 28.7 wells vs. 18.3 wells Early production: Incremental wells on production 10.4 wells / yr Improved efficiency of operator's organization

 

Example of Best Value: H"&"#038;P FlexRig3s Example of Best Value: H"&"#038;P FlexRig3s Rocky Mountains

 

Safety Efficiency The future is about applying better ideas New appreciation of H"&"#038;P's value proposition Outstanding financial returns Why Do We Favor a New Build Strategy?