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 9, 2012 (April 5, 2012)

Helix Energy Solutions Group, Inc.

(Exact name of registrant as specified in its charter)

Minnesota (State or other jurisdiction  of incorporation)	001-32936 (Commission File Number)	95-3409686 (IRS Employer Identification No.)
400 N. Sam Houston Parkway E., Suite 400 Houston, Texas (Address of principal executive offices)	281-618-0400 (Registrant’s telephone number, including area code)	77060 (Zip Code)

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):

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

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

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

|_| Pre-commencement communications pursuant to Rule 13e-4(c) under the Exchange Act (17 CFR 240.13e-4(c))

Item 7.01 Regulation FD Disclosure.

Helix Energy Solutions Group, Inc. (the “Company”) will host an Analyst Day on South Padre Island on April 9, 2012 and a tour of its Q4000 well intervention vessel on April 10, 2012.  The press release announcing these events is attached hereto as Exhibit 99.1 and the presentation materials to be delivered at the Analyst Day are attached hereto as Exhibit 99.2.   Each of the exhibits is incorporated by reference herein. The presentation materials have also been posted in the Presentations section under Investor Relations of Helix’s website, www.HelixESG.com.

 This Form 8-K contains forward-looking statements that involve risks, uncertainties and assumptions that could cause our results to differ materially from those expressed or implied by such forward-looking statements. All statements, other than statements of historical fact, are "forward-looking statements" within the meaning of the Private Securities Litigation Reform Act of 1995, including, without limitation, statements regarding the well intervention market and the characteristics and effectiveness of certain proposed vessels. The forward-looking statements are subject to a number of known and unknown risks, uncertainties and other factors including but not limited to the performance of contracts by suppliers, customers and partners; actions by governmental and regulatory authorities; operating hazards and delays; employee management issues; uncertainties inherent in the exploration for and development of oil and gas and in estimating reserves; complexities of global political and economic developments; geologic risks; volatility of oil and gas prices and other risks described from time to time in our reports filed with the Securities and Exchange Commission ("SEC"), including the Company's most recently filed Annual Report on Form 10-K and in the Company's other filings with the SEC, which are available free of charge on the SEC's website at www.sec.gov. We assume no obligation and do not intend to update these forward-looking statements except as required by the securities laws.

Item 9.01   Financial Statements and Exhibits.

(d)           Exhibits.

Number                      Description

----------                      --------------

99.1   Press Release dated April 5, 2012 announcing Helix hosting an Analyst Day on April 9, 2012 and Q4000 Tour on April 10, 2012.

99.2   Materials to be presented at the Analyst Tour of Q4000.

SIGNATURES

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.

Date:           April 9, 2012

HELIX ENERGY SOLUTIONS GROUP, INC.

 By:              /s/ Anthony Tripodo                                                                           

 Anthony Tripodo

 Executive Vice President and Chief Financial Officer

Index to Exhibits

Exhibit No.                                Description

99.1   Press Release dated April 5, 2012 announcing Helix hosting an Analyst Day on April 9, 2012 and Q4000 Tour on April 10, 2012.

99.2   Materials to be presented at the Analyst Tour of Q4000.

EX-99.1

EXHIBIT 99.1

PRESSRELEASE www.HelixESG.com  

Helix Energy Solutions Group, Inc. ·  400 N. Sam Houston Parkway E., Suite 400  ·  Houston, TX  77060-3500  · 281-618-0400  ·  fax: 281-618-0505

For Immediate Release                                                                                                                                          12-008

Date:  April 5, 2012                                                                 Contact:                  Terrence Jamerson

Director, Finance & Investor Relations

Helix to Host Analyst Day and Q4000 Tour

HOUSTON, TX – Helix Energy Solutions Group (NYSE: HLX) will host a half-day meeting on South Padre Island for analysts and trade journalists on Monday, April 9, 2012, beginning at 4:00 p.m. Central Daylight Time and a tour of the Q4000 the following morning, which is at dry dock in Brownsville, Texas. The event will include an overview of well intervention, a review of Helix’s well intervention fleet, and a discussion of well intervention methodologies. Investors and other interested parties will be able to obtain the slide presentation on the date of the event from the “Investor Relations” page at www.HelixESG.com by clicking on “Investor Relations” and then choosing “Presentations”.

About Helix

Helix Energy Solutions Group, headquartered in Houston, Texas, is an international offshore energy company that provides development solutions and other key life of field services to the energy market as well as to its own oil and gas business unit. For more information about Helix, please visit our website at www.HelixESG.com.

EX-99.2

Changing the way you succeed.

Owen Kratz, Helix ESG Chairman and CEO

Well Intervention
Overview

1

What is well intervention?

2

•Well intervention is the ability to safely enter a well with well control for the
purpose of doing a number of tasks other than drilling.

•Well intervention historically was done with drill rigs, with an 18-3/4” BOP and
21” marine riser as the only means of well access with well control.

•In the 80’s, technology was developed that afforded for re-entry into wells with
alternatives to the drilling well control systems and rigs for delivery of non-
drilling services.

•As technology is developed, water depth increases, well head design evolves
and well construction changes, intervention also evolves and demand grows.

Intervention Today

3

•Xmas tree recovery/installation

•Xmas tree/wellhead maintenance

•Choke change-out

•Light construction

•Saturation diving (inspection, repair & maintenance)

•ROV support services

Future Applications of Some Intervention Assets:

•Through tubing well intervention

•Top hole drilling

•Extended top hole drilling

•Riserless Mud Return

•Subsea Rotary Controlled Device

•Well flowback and Well testing

•Subsea Construction

4

Related Operations with Intervention Assets

Downhole Well Intervention Solutions

üFirst Subsea Intervention Lubricator
operations in the North Sea

üFirst build and launch of dedicated
intervention vessel - Seawell

üFirst coil tubing deployed on a
subsea well from a rig alternative
monohull

üBuild and operation of prototype
vessel Q4000

üFirst rig alternative
decommissioning of offshore
production facility with multiple
subsea wells

üFirst application of Huisman
multipurpose tower

Helix Intervention Industry Firsts

•As production goes to deeper water, subsea wells market grows.

•As the number of subsea wells increase and they age, the demand and
frequency of required servicing through intervention grows.

•The market is in its infancy with huge growth potential.

7

Growing Market

Well Intervention Demand Drivers

8

Global offshore rig count

•Declining shallow water
resources have spurred
technical advances that allow
offshore exploration and
production in deeper, harsher
environments

•New discoveries and
pressure to improve recovery
rates from developed fields
increase demand for subsea
intervention

•Subsea trees are expected to
increase at an 18.3% CAGR
and global offshore rig count
is expected to increase at a
5% CAGR from 2010 to 2015

The global subsea intervention market is expected to expand as the focus of offshore drilling
shifts to more challenging environments

Source: Spears & Associates, Quest Offshore Resources

Intervention Needs Rises with Subsea Well Count

Source: Quest Offshore Resources

Subsea wells installed base (2002 - 2012)

Installed subsea completion base over 5 yrs
old

Installed subsea completion base 5 yrs
or younger

Note: Total installed base includes all subsea well completions from 1990, not adjusted for wells decommissioned 2007-2012

■Need for intervention typically
occurs after 5 years of
production, due to:

–Reduced pressure in wells

–Increased water or sand
production

–Scaling in wells

–Other factors

■Oil wells generally have a
greater need for intervention
than gas and injection wells

+200
%

+94%

Market Outlook for Well Intervention

10

•Subsea intervention demand driven by increasing activity and rising
subsea well counts

•Maintenance intensity expected to rise as greater share of production
moves into deepwater fields and as operators face increasing oil
recovery needs from maturing fields

•Global expenditures on intervention are expected to grow 11%
annually from 2009 to 2014, reaching nearly $3.8 billion

Subsea well intervention expenditures

Source: Douglas-Westwood

2011 Market for Well Intervention Services

11

North America

SS Intervention spend:$470mm

Offshore rigs:31

Offshore wells drilled:260

Latin America

SS Intervention spend:$427mm

Offshore rigs:88

Offshore wells drilled:572

United Kingdom

SS Intervention spend:$272mm

Offshore rigs:16

Offshore wells drilled:157

Norway

SS Intervention spend:$303mm

Offshore rigs:19

Offshore wells drilled:188

Africa

SS Intervention spend:$746mm

Offshore rigs:37

Offshore wells drilled:531

Asia Pacific

SS Intervention spend:$375mm

Offshore rigs:80

Offshore wells drilled:1,072

Source: Douglas-Westwood, Spears & Associates

Regulatory Limitations

Vessel Class - Many independent classing societies

•Most Prominent - DNV (Det Norske Veritas),
ABS (American Bureau of Shipping)

•MODU Notation - Specific requirements for a vessel used in intervention
including zoning for handling hydrocarbons.

•Government - No international standard.All strictly enforced by each country.

•Prescription vs. Safety Case

Client - Every client and sometimes every engineer has a different set of
compliance standards.Now driven by SEMS.

Industry - Many depositories of guidance principles.

•Voluntary Compliance

•Generally accepted by Industry but different clients will look at different
sets of guidance.

•APL - Most generally accepted.

12

13

Wireline Deployment via SIL

•7-3/8” bore, 10ksi WP - single trip

•600 m water depth rated

•Various wireline & coiled tubing modes
with sub-modes (long and short tools,
etc.)

•Live well decommissioning & stimulation
modes

•Balanced stabs with valves

•Modular design

•LRA / URA - VXT, HXT & CT riser

•URA only - VXT wireline

•Dual BOP position

•18.5 m or 22 m toolstrings

•Norwegian compliant

•Except DNV-E-101 re: QOD

•Minor lessons learned in next version

SIL Overview - MUX Controls

MUX EH control system

•Mode Screens

•Auto Set Interlocks

•Configuration, Set Up & Test, Lifting Ops

•Slickline, Braided Line & Riser

•ROV electronics technology

•Grease system same as Seawell & Enhancer

•Not electric pump - seawater powered from surface

•No wireline shear upon subsea comms failure

•6hrs POOH - batteries & surface grease pump

•Auxiliary umbilical option to LRA / URA & extend

•ROV controls

•Full LRA WCE

•Primary URA safety functions

•Client Mimic Screen

14

Intervention Riser System for CT Deployment

•As water depth increases, the cost of intervention increases. If a problem
is encountered, wireline alone is limited in being an effective
remediation tool.

•To run coiled tubing into a well requires either an absurdly complicated
well head mounted system or requires a riser back to the surface.This
creates an extremely complicated interface occurring between the
stationing riser and a tugging mooring vessel.These relative motions and
the fact that the interface between the well’s high pressured hydrocarbons
and the low ambient pressures on the vessel creates technical
challenges.

15

Compensation
Frame CCTLF

Flow Tee and Swivel

Riser Centraliser

Moonpool Joint

Fatigue Enhanced Riser

Mid Joint Connector

Stress Joint

SIL including EDP
Assembly

Multi Purpose Tower
MPT

Helix Coiled Tubing Setup

Vessels - Category A Intervention

Category A - Wireline only deployed via a SIL.Typically a monohull due to
build cost and spend of transit.

•Smaller the better to keep costs down commensurate with limited
capability.

•Limited deck area required for necessary equipment.$110 million and
larger typically.

•Operability limited if size is so small that motions become too great for
safe operating.Has even greater effect in harsh environments

•Water depth limited by seal technology and cost associated with
complexity of system required to accommodate depth.

17

Vessels - Category A+ Wireline

18

Category A + - wireline and coiled tubing deployed via SIL and sub 7” riser,
i.e. drill pipe.Also typically a monohull.

•Greater capability with CT but unable to work full bore 7” which restricts
what can be done.

•Advantage of being smaller and lower cost.

•Motions are high thus complexity is difficult.

•High motions result in narrow operating envelope resulting in more down
time and higher risk if emergency disconnect is required.Smaller vessel
makes it difficult to be able to operate on station in high seas.

•High motions adds to safety risk, i.e. man riding.

Vessels - Category A++ Intervention

Category A ++ - Wireline and CT deployed via a 7” riser.

•Has full bore capability with coiled tubing through full 7” bore of the
well.

•May have limited capability of pulling tubing.

•Size of the vessel increases deck space required for equipment and
riser handling.

•Larger size vessels handle sea motion better.

•System required to compensate for motions is still relatively complex.

•Overall cost is now getting high.

19

Vessels - Category B Intervention

Category B - Semi Submersible

•Ample deck area

•Motions are the best and allows for less complexity and risk in systems
design.

•Greatest number of applications possible.

20

Industry Considerations

21

Determining which solution makes sense is a balance between
small, low cost vessel with a complex high risk system. (Technology
is not fully developed)

Or

Larger, high cost vessel with simpler low risk system.

Primary Focus: Semi Platform Deploying IRS

22

Conclusion

Colin Johnston, Helix Well Ops Senior Engineer

Well Intervention
Fleet Overview

1

2

MODU DP3 Q4000

MSV DP3 Well Enhancer

Vessel of opportunity

MSV DP2 Seawell

Well Intervention Assets

Helix is the leader in subsea through-tubing
intervention

•Global Reach

•24 years experience in the North Sea on more
than 600 wells

•14 years experience in the Gulf of Mexico on
more than 100 wells

•5 years experience in Australia & Sea East Asia
on more than 20 wells

•Successful application of prototype equipment

•Q4000 - IRS, HFRS, MPT, VDS

•Well Enhancer

•Track record of cooperative contracting and
scheduling

•Gulf of Mexico

•North Sea Collaboration - Multi client

•Helix Well Containment Group

•Proven capability to manage:

•Marine vessels,

•Crewing

•Subsea systems

•Subsea controls, downhole services, diving,
construction, and WROV operations

•Well Enhancer CT system

•WOUS IRS MUX upgrade

3

Providing World Class Intervention Services

History and Evolution - Seawell

4

5

History and Evolution - Well Enhancer

6

History and Evolution - Vessels of Opportunity

7

History and Evolution - Q4000

Where the value is found

•Efficiency - Main Driver

•Time efficient

•Cost efficient

•Campaign Based

•Shared across BU, Assets,
Operators

•Broad Functionality

•Minimal Built-ins

•Variable deck lay out

•Construction Support

•Construction and well intervention
capability

•Seabed access and recovery

•Emergency Response

•Knowledgeable, integrated crews

•Integrated Onshore Management

•Assessment and investment in new
technology

•Integration of Technology

8

9

Accommodation (122)

&project offices

18 man saturation

1 x WROV

1 x Obs ROV

Active heave-comp Derrick

Twin Crane & Well
Services spread:

Slickline

E-line

Pumping

Well test

•Main deck

•(Client supplied)

•Below deck

•2 x drill water tanks 258m3

•4 x bulk fluid tanks 240 m3 (1509 bbl)

114m

•Derrick Lifting Capacity 80Te

•Crane 130Te (twin lift)

•2 x 15k psi OPI triplex pumps

Seawell Light Well Intervention Vessel

10

•Main deck

•1 x bulk fluid tank 150m3(943bbls)

•Below deck

•2 x drill water tanks 90m3 each

•1 x bulk fluid tank 190m3

•Tower Lifting Capacity 100Te

•Crane 150Te

•2 x 10k psi SPM600 pumps

Well Services
spread:

Slickline

E-line

Pumping

Well test

Coiled Tubing

Active heave-comp Tower, Crane, Riser Handling & Skidding system

18 man saturation

1 x WROV

1 x Obs ROV

Accommodation (120)

& project offices

132m

Well Enhancer Light Well Intervention Vessel

11

7 3/8” SIL in the Well Enhancer Tower

5 1/8” SIL in the Seawell Derrick

7 1/16” SIL in the Seawell Derrick

Subsea Intervention Lubricators (SILs)

Well Enhancer - Overview

Tower, Riser Handling

& Skidding systems

Crane & Well Services

•Slickline

•E-line

•Pumping

•Well test

•Coiled Tubing

•Tower Lifting Capacity = 150Te

•Tower Active Heave Comp = 130Te

•Crane = 100Te

•Guide Line Tensioner = 4 off (10te)

•Active Pod Line Tensioner = 2 off (15te)

•2 x SPM600 673kw 10k pumps

•1 x s/steel frac tanks = 200 m3 (1260 bbl)

•2 x drill water tanks = 190m3

•Deck tanks = >266m3

Compensation
Frame CCTLF

Flow Tee and Swivel

Riser Centraliser

Moonpool Joint

Fatigue Enhanced Riser

Mid Joint Connector

Stress Joint

SIL including EDP
Assembly

Multi Purpose Tower
MPT

Well Enhancer Coiled Tubing Setup

Q4000 DP3 MODU Semi-submersible

14

4,000 mT variable main deck load

•MPT Tower Lifting
Capacity 600 mT

•Active and Passive Heave
Comp

•360 mT Huisman crane
with
10,000 ft capacity traction
winch

Well Services spread:

Slickline

E-line

Pumping

Well test

Coiled Tubing

Active heave-comp Tower, Crane,
Riser Handling & Skidding system

Accommodation (133)

& project offices

Well Ops 7-3/8” Intervention Riser System

Future Vessels

•Through tubing well intervention

•Top hole drilling

•Extended top hole drilling

•Riserless Mud Return

•Subsea Rotary Controlled Device

•Well flow back, well testing

•Subsea construction

•Subsea processing support

•Open Water Completions

Kurt Hurzeler, Helix Well Ops Commercial Manager

Well Intervention
Methodologies

1

Critical Skill Sets

•Specialized vessels and vessel
management

•Down hole & Service Options
expertise

•ROV expertise

•In-house Subsea expertise

•Construction expertise

•Saturation Diving expertise

•Multi Functional Crew Management

Vessel Functions

•Adequate usable Deck space

•Adequate Accommodation

•Certified and classed for
hydrocarbons on deck

•Lifting Capacity and Stability

•Heavy weather dynamic positioning

•Fluid storage and handling

•IRS tubular handling and tensioning

ConsistentSuccess Requires…

Facilitate Wellbore Access

•Flexibility of system to interface with all subsea well types with minimal
modification.

•Provide systems on a day rate basis to reduce end user’s cost

•Minimize complication, deployment and testing time

•Reduce rig requirements and costs

Reduce Decommissioning Liability

•Lower cost well abandonment

•Reliable and successful completion

Improve Intervention Response

•Provide a rig alternative with 4 season capability.

•Minimize mobilization, demobilization and transit time

•Pre-engineer capability to allow rapid response for clients needs

•Stay in the field

Provide Surveillance & Flow Assurance

•Reduce access costs for subsea production evaluation

•Reduce Inspection, Repair & Maintenance (IRM) Costs

Where the Value is Found

Campaign Based

•Shared costs across BU’s, fields and operators

•Reduced transit time

•Minimal port and duty costs

Construction Support

•Ability to carry out construction and well intervention

•Lift and/or transport heavy equipment from port to location, install via
crane or drillpipe, assist platform operation

Emergency Response

•Offshore fire fighting, diving and ROV support

•Ready availability, construction, accommodation, intervention and
general operations support

Where the Value is Found

Operational overview - Seawell North Sea

The Client objective was to maximise
the operational functionality of the
MSV Seawell in order to complete the
following well workscopes:

•Mechanical repair/well
maintenance/integrity

•Production logging

•Mechanical repair/well maintenance;
tree change-out; well integrity

•Well suspension operations
(temporary abandonment)

•3 x well P&A and wellhead removal

•Pumping - scale-squeeze operations

Operational overview - Seawell North Sea

•In field 16 days Highlander Field

•In field 16 daysTartan Field

•In field 14 days Enoch / South Wood

•In field 17 daysClaymore

•In field 9 daysTweedsmuir

5 1/8” SIL in theMSV Seawell Derrick

Seawell Operation summary

•Number of well locations = 7

•Water depth range = 90 - 141m

•Full demobilisation of 5 1/8” SIL in order to mobilise 7 1/16” SIL for TNT

•Total days = 68

•Vessel off-hire 0 days

•Wait on Weather9.5 days

•Uptime 58.1 days

•Well-work completed:

•4 Interventions (Well Maintenance & Production Enhancement)

•3 wells P&A’d (Decommissioning)

•All the above workscopes were supported with Saturation Diving operations

•All procedures developed and work supported by in-house WOUK project engineers

Q4000 Gulf of Mexico Snapshot

Q4000 Gulf of Mexico Snapshot

Q4000 Deck Layout for Well Stimulation

Deck Space- More is Better

Drilling module roofs with complete coiled tubing system, E
-Line, Slick Line, fluids and second WROV system

Intervention Deck Space and Positioning

•Coil-tubing Lift Frame

•Intervention Riser Package

•Flowhead

•H4 Connector

•Riser

•3rd Party Service Equipment

Critical Components Remain Onboard

280 MT Manifold being deployed

Construction- Dock to Seabed

•Seabed debris recovery

•Debris cap recovery and
reinstall

•Flowline plug and burial
Flowline clean out

•Jumper disconnect and
recovery

Construction - Concurrent Operations

Static Kill

Oil & Gas Burn

Dynamic Kill

SIMOPS

Q4000 Versatility and Capabilities

Summary

•A unique combination of specialized skills and equipment

•A clear understanding of Client value

•Recognition of operational technical limits

•The means, ability and experience to manage and control diverse assets and
personnel effectively and reliably

Helix Well Ops Provides