Itf Closed Project List Dec 11

Project Listing

Industry Technology Facilitator - Project List (With Summaries)

Status: JIP Closed

Project No. : 1001 PWD ITF Funding (£k): 338 Duration (Months): 9

Summary: The first phase of the project, Preliminary Engineering, completed May 2001 was sponsored by: Shell UK, BP, BG Group, Statoil and Veba Oil & Gas. This phase demonstrated that

a system (Coupler and Control System) could be designed to make/break drill pipe connections under typical drilling conditions while diverting drilling fluid downhole. The

system is designed to handle pipe from 3 /12” to 5 7/8” o.d.The design embraces a mechanical device for making drill pipe connections on the rig floor and encompasses a

snubbing device, grips and drilling fluid diverter to allow pressure and circulation maintenance during drilling, connections and, eventually tripping.

The Coupler development is phased over 4 phases to phase expenditure and mitigate development risks associated with an innovative drilling technology. Phase I was

successfully completed May 2001 on-time and within budget. Phases 2 (Detailed design & component testing) and 3 (Prototype Manufacture) are being undertaken during 2001-

2 and require additional funding support. Phase 4 is divided into two sub-phases: 4A - Mechnical Trial on a test rig & 4B - Drilling Trial on an operational Land drilling Rig. These

are scheduled for 4Q 2002 and 2Q 2003 respectively and depend on a client providing a rig and well for a field trial. The work phases will also require industry support. Varco will

fund Phase 3.

Project Objectives are:

a)Complete the detailed design and test components of a drilling coupler within January 2002

b)Develop a well applica@ons strategy and rig interface designs for rigs with Top Drives

c)Create a ‘step change’ in the way wells are constructed through increased drilling performance and an enabling technology

Title: The Continuous Circulation Coupler Development Project

Sponsors Confirmed: BG Group, BP, Shell, Statoil, Veba

22 December 2011 of 71



Summary: Objective:

- To build and test demonstration imagers, capable of seeing through crude oil.

- Establish their performance envelope. Improve the understanding of imaging in oil.

- Identify new imager applications.

Status, Findings and Plans:

- Two versions of the imager (self-contained, downwards-looking and sideways-looking) were constructed, and demonstrated operating in crude oil in laboratory tests. High-

resolution video and still images were obtained, in crude oil, of objects such as welds, corroded and cracked steel samples, downhole equipment and tubing. Operation in

different oils was investigated and techniques to predict performance were established. Operation in both oil and water simultaneously and the ability to distinguish between

them on command (i.e. see through oil and water or detect one in the other) were also demonstrated.

The testing showed that down-hole applications of the imager will include:

- Identification of obstructions;

- Corrosion and damage inspection;

- Verification of component placement (e.g. gas-lift valves);

- Wireline-deployed well head plug verification;

- Sand-control device inspection;

- Visualization of complex multiphase flow.

In addition, non-down hole applications have now been identified such as:

- Internal inspection of FPSOs and land storage tanks for weld integrity;

- Corrosion and sediment build-up;

- Internal inspection of pipe-lines, flow lines and refinery pipework;

- Multi-phase flow visualization to optimise process plant operating efficiency.

The JIP successfully took the technology from an initial laboratory demonstration of the principle to the basis for commercialising practical tools.

The results, including still clips from the captured video, were published in three SPE technical conference papers:

- SPE 71465 - Imaging through Crude Oil with High Resolution, Optically

- SPE OTC 14194 - Seeing Through Crude Oil – Results from Demonstrator

- SPE 3980 - Seeing through Crude Oil – Results from Prototypes

Commercialisation planning is now in progress, addressing the following applications:

Title: Downhole Imager

Sponsors Confirmed: BP, Chevron, Hess, Shell



- FPSO and crude oil storage tank inspection;

Project No. : 1007 PWD SCORE ITF Funding (£k): 105 Duration (Months): 18

Summary: Core data acquisition is the only non-derived source of data but the cost of acquisition is high. This results in a commercial driven preference of lower quality data. In other

words, existing technology fails to meet specific needs of the customer base.

The SCORE project is designed to develop and demonstrate tools and systems that will allow oilfield (and potentially other explorers/drilling entities) operators to acquire core

data from the side-wall of wells that have been drilled and logged.

The development of a tool that enables a change to the timing of core acquisition until after the well is drilled and logged changes the level of risk.

This allows strategic changes to the way exploitation drilling is conducted, changing the timing and amounts of costs incurred.

By enabling the process to be aligned to specific data needs the cost of acquiring higher quality data acquisition is also substantially reduced.

The SCORE technology has been shown to work in real oil-field conditions. However, results have been inconsistent in poorer quality wells. To become established as a best

practice tool, modifications to the system are required to deliver the ability to consistently produce good quality performance in tight or oversize wells.

The project also aims to use the wireline to communicate with the coring assembly to move away form the “black art” approach that currently bedevils coring. To round the

activity, it is also intended to integrate the analysis of the core to deliver high quality core data in a wellsite high quality package that can be easily merged into current well data

reports and deliver them prior to the core leaving the wellsite.

The project will be phased to enable feedback to modify detailed objectives as results are achieved. This also enables participant consortium membership to vary, reflecting

differing participant interests.

Title: Coring after logging

Sponsors Confirmed: BP, Eni, Total



Project No. : 1012 PWD ICT ITF Funding (£k): 60 Duration (Months): 6

Summary: This project will produce a multi functional coiled tubing umbilical which will offer a highly cost effective product available in many options.

Objective;

The concept is to provide sandwich conductors/control lines in a steel/steel or steel/composite dual skin coiled tubing umbilical.

The umbilical, termed Intelligent Coiled Tubing, or ICT, provides a flush internal bore combined with high power electrical, hydraulic and optical data transmission capabilities.

This umbilical offers;

1.Increased safety - dual skin.

2.Conven@onal or exo@c steel construc@on combina@ons.

3.Hybrid construc@on - composite external skin with steel liner.

4.Reduced weight, enhanced extended reach drilling capability.

5.Small diameter flexible risers/umbilical capability.

6.Heated flow lines - by product while transmiLng electrical power.

7.Mul@ pumping systems - 100km small diameter flow lines.

8.Mul@ trac@on systems - 20 km extended reach wells.

9.Smart comple@ons with increased reliability.

10.Embedded sensors, - well diagnos@cs or geomapping capabili@es.

11.Few connec@ons, less leak paths.

12.Factory assembled, quality assured before arriving on loca@on.

13.Live well deployment and recovery.

14.MW electrical power for unlimited applica@ons.

15.Significantly reduced CAPEX and OPEX.

This project will deliver;

XLTL intends to conduct a feasibility study into the most suitable forms of dual skin ICT. This will then move rapidly into a bench testing the most promising concept.

The budget for the feasibility and bench testing is estimated to be £60,000. The project is scheduled to kick off in July 2000.

Upon satisfactory completion a full scale manufacture and test program will be prepared, costed and presented to participants.

Title: Intelligent Coiled Tubing

Sponsors Confirmed: BP, Shell




Summary: Global Marine Integrated Services (GMIS) and Leading Edge Advantage (LEA) propose to work together to quantify the potential benefits and identify the major issues and risks

associated with conducting an under-balanced drilling project in the UKCS. Risk mitigation measures, competent service company resources available and typical planning

required to conduct such a project will be detailed. The objective of the project is to accelerating the uptake of the technology by removing much of the “fear of the unknown”,

which is currently restricting the rate in which under-balanced drilling projects are being undertaken in the UKCS.

It is hoped that a JIP to cover this research and make the findings available to the industry may lead to a collaborative sequence of under-balanced drilling projects carried out by

a number of operators.

Title: Underbalanced Drilling – UKCS Independent Technology Acceleration Initiative

Sponsors Confirmed: BP, ConocoPhillips, DTI, Hess, Statoil

Project No. : 1024 PWD DECT ITF Funding (£k): 175 Duration (Months): 18

Summary: - Market assessment of current downhole tubular cutting methods

- Evaluate best electrical/mechanical cutting method for majority of oil field tubular materials

- Evaluate market for cutting various pipe sizes and target initial design for most common size

- Mechanical and electronic design of prototype tool, including modular features for later expansion.

- Manufacture two production prototypes

- Test prototypes a) in laboratory on oil field steel samples and b) in the field

- Product launch given successful test results

Title: Downhole Electric Cutting Tool

Sponsors Confirmed: BP, Chevron, Enterprise, Maersk, Shell, Statoil, Talisman



Project No. : 1027 PWD STAF ITF Funding (£k): 100 Duration (Months): 12

Summary: Scope

- TAF is a key project to extend slickline life and therefore reduce cost and increase safety

- The STAF software fatigue model will be complete and able to perform effectively in conjunction with CTES ReelTrak

Benefits

- Accurate fatigue tracking will:

- Extend life and therefore reduce cost for high cost slicklines

- Improve safety – considerably less likelihood of wire severing at surface

- Reduce downtime resulting from slickline failures thus reducing number of high risk fishing operations

- Increase customer confidence in slickline operations

Business Case

- Sicklines suffer from fatigue during their service life. STAF would record fatigue damage caused by each trip, ensuring retirement before wire failure

- Can be used in conjunction with existing software programs: ‘Achilles’ Coiled Tubing fatigue model and ‘ReelTrak’ to track the working lifespan of all strings in use.

Title: Slickline Testing and Analysis for Fatigue

Sponsors Confirmed: BP, Shell, Total

Project No. : 1030 PWD D2 ITF Funding (£k): 120 Duration (Months): 6

Summary: This proposal addresses the issue of the costs of drilling an exploration well by taking a fresh approach which builds on the Finder Well initiative originally set up through CRINE.

Although some companies do better than others the failure rate of exploration wells is a strong financial disincentive to exploration especially where smaller, perhaps

commercially less robust, fields are concerned.

The concept is based on the development of a seabed based, all electric, coil tubing exploration unit that will be deployable from an appropriate vessel of opportunity and

capable of drilling to at least 15,000 feet. With recent developments in electric CTD motors, tractor technology and micro instrumentation it is believed that a technically viable

and economically much more attractive system is now capable of being designed and developed and that it will be capable of operating in both N Sea type depths and ultimately

in ultra deep water as well.

Title: Deep Driller

Sponsors Confirmed: BP, DTI, Shell



Project No. : 1032 PWD SLIMWELL ITF Funding (£k): 233 Duration (Months): 24

Summary: Slimwell construction or more appropriately slim clearance is a method of constructing a well, exploiting the use of flush jointed casing, deployed as a series of liners and

employing a novel circulation system to avoid excessive swab/surge pressures during deployment.

The main technical challenges to overcome were:

1.Novel Circula@on system; A consequence of construc@ng the well as a series of liners is that each new liner deployed can be fiQed with a s@nger tube which when combined

with porting in the float shoe provides an additional flow path for fluids to equalise across the liner while it is being conveyed past the internal diameter of the last liner. This

results in circulation pressures very similar to those experienced during the drilling process.

2. Dimpled liner hanger; How to terminate each liner hanger with so liQle annular space while s@ll retaining the same tensile load capacity as the virgin pipe. This was achieved

by engineering a unique liner hanger system which requires no moving components, and which formed a hybrid elastomer and metal to metal seal with the previous liner.

Title: SLIM CLEARANCE WELL CONSTRUCTION CIRCULATION SYSTEM

Sponsors Confirmed: BP, Hess, Shell


Summary: To specify, design, prototype and successfully test a mechanical tractor based on the existing Omega Tractor, for Slim or Slender well applications.

Title: Omega Slimhole Tractor

Sponsors Confirmed: BG Group, BP, Shell

Project No. : 1040 PWD DCW ITF Funding (£k): 78 Duration (Months): 9

Summary: The Romar Drill Cuttings Wash system works on the principle that Oil floats on water, and that it is possible to “scrub” oil from solid particles. It involves a carefully designed

circulating system that induces agitation of the solids within the fluid, displacing the oil. The oil is then suspended in the fluid while the cleaned cuttings are discharged for

disposal. The differential density separation releases the oil, which is drained off and can be returned back to the mud company to be used again.

The initial use for this system is to assist with onshore processing alongside thermal plant operations; this will speed up processing times and reduce costs. The ultimate use for

the system is to process cuttings offshore so that they can be discharged overboard with zero chemicals or contaminants.

Title: Romar International Drill Cuttings Wash System

Sponsors Confirmed: BP, Chevron, Hess, Shell



Project No. : 1042 PWD Mole Anchor ITF Funding (£k): 300 Duration (Months): 12

Summary: This project offers a very low cost method of installing an anchor into the seabed to achieve a known and guaranteed pull out capacity.

The development process during phase 2 has resulted in significantly simpler and even more cost effective anchor deployment system. The main outcome from phase 2 is;

1. Anchor is now deployed by winch line over the back of a standard plaRorm support vessel, (minimum vessel equipment required)

2.Anchor burrows itself to the required depth of opera@on. 0.75S/min was achieved during the final scale tests of phase 2. We are confident this can be increased to at least

1ft/min. ( anchor will penetrate to required soil strength)

3. Anchor can be powered by ROV wet stab mate able connector or electrical line from vessel.

4.In one design embodiment anchor will be fully retrievable.

5.Economic impact indicates significant OPEX and CAPEX savings for both MODU and permanent pre-set mooring installa@ons.

Title: CT Deployed Moorings


Project No. : 1046 PWD Scalesense ITF Funding (£k): 300 Duration (Months): 15

Summary: This proposal aims to make available to the market a reliable, robust, downhole chemical sensor for pH, chloride and barium and that can be easily integrated into Industry

standard downhole monitoring systems. Tasks are: to develop a barium sensing element to integrate with chloride and pH sensors developed previously; to productionise the

sensors; to assess the reproducibility and reliability of the productionised sensors and to undertake site trials. AEA Technology will be responsible for development,

productionising and assessment of the sensors. Wood Group Production Technology will have design responsibility for integrating the sensor into their downhole system, and

will be responsible for site trials and providing the route to market. This programme builds on previous industry funded work to develop pH and chloride sensors, and aims, in an

accelerated timescale, to undertake the work required to take downhole chemical sensors into practice.

Title: Downhole chemical sensors – Barium electrode and productionising

Sponsors Confirmed: BP, Chevron, Shell, Total



Project No. : 1050 PWD Datalink ITF Funding (£k): 186 Duration (Months): 12

Summary: Information is paramount in making informed decisions. Large volumes of data are generated while drilling a well, and discarded. Ideally, the information would be transmitted

to the surface immediately. The bottleneck with existing technology is the data transmission process (about 2-4 bit per second). This compromises information gathering while

drilling and necessitates subsequent expensive wireline logging.

The technology proposed in this project offers telemetry at rates in excess of 1,000,000 bits per second. When successfully implemented it will allow in real time bi directional

communications to enable;

Look ahead and VSP seismic while drilling

Acoustic imaging

Resistivity imaging

In-flow, borehole pressure monitoring impacting well control and stuck pipe issues

BHA steering and bit / motor condition monitoring,

to name but a few.

Title: Fibre optic telemetry system for jointed drillpipe application

Sponsors Confirmed: BP, Shell

Project No. : 1056 PWD CCC ITF Funding (£k): 1000 Duration (Months): 6

Summary: The Coupler development is phased over 4 phases to mitigate development risks associated with an innovative technology. The first phase was successfully completed May 2001

on-time and within budget. Phases 2 (Detailed design & component testing) and 3 (Prototype manufacture) are being undertaken in 2001-2, with Phase 3 requiring additional

funding support. Phase 4 (Mechanical trials and Drilling trials on a Land Rig) are scheduled for Dec 2002 and April-May 2003. The Mechanical and Drilling field trials will also

require industry support. Project Objectives are:

1.Complete the detailed design and test components of a drilling coupler within January 2002

2.Develop a well applica@ons strategy and rig interface designs for rigs with Top Drives

3.Create a ‘step change’ in the way wells are constructed through increased drilling performance and an enabling technology

Phase 2 is primarily concerned with detailed engineering and control system design, component testing and evaluation of suitable thread lubricant compounds for use in tool

joint make-up/breakout.

Title: Development of the Continuous Circulation System: Phase 2- Detailed System Design & Component Testing

Sponsors Confirmed: BG Group, BP, Eni, Shell, Statoil, Total, Varco




Summary: The use of microwaves provides a versatile tool for processing a range of materials that is both compact and energy efficient. The aim of the proposed research programme is to

develop an industrial scale microwave assisted pyrolysis (MAP) facility for treating oil contaminated drill cuttings (OCDC). Laboratory-scale batch experiments will be conducted

using a 15 kW microwave facility to ascertain the effects of residence time, particle size and mineral composition on the thermal desorption/ pyrolysis behaviour of the diesel.

The results will form a basis for conducting continuous processing experiments where the OCDC will be fed through the microwave applicator pneumatically. Finally, based on

the results obtained for continuous processing using a 15 kW microwave generator, a facility for treating 10-30 tons of OCDC per hour will be designed which will be sufficiently

compact to fit into an area of 15’ by 10’ for offshore operation.

Title: Microwave Assisted Pyrolysis for the Treatment of Oil Contaminated Drill Cuttings

Sponsors Confirmed: BP, Hess, Shell

Project No. : 1084 PWD Rotomill™ ITF Funding (£k): 220 Duration (Months): 14

Summary: Continue the incremental innovation process to transform the recycling unit, through entrepreneurial skill and proof of concept to a successful production scale trial unit.

To assist TWMA to grow as a commercial and successful service company to the oil sector

To contribute to the minimisation of environmental impact of oil sector operations through market development and application of this process

To further prove the feasibility and concept of both onshore and off-shore recycling of mud cuttings at production scale

Title: Offshore Drill Cuttings Recycling Process Development

Sponsors Confirmed: Shell, Total

Project No. : 1087 PWD Microencapsulating

detergent

ITF Funding (£k): 30 Duration (Months): 12

Summary: MicroScience Technologies has created a new type of detergent that, in the presence of water or brine, microencapsulates hydrocarbons (oils). These detergents can be used for

the removal of oil from drill cuttings. The cuttings are simply mixed with a solution of the detergent in water. The microcapsules form almost immediately and disperse in the

water. The detergent solution will absorb its own weight of oil. The oil-free cuttings are removed by centrifugation or by other suitable means. The oil content of the recovered

cuttings is around 0.5%.. The exact design of the detergent needs to be perfected so that full recovery and recycling of the detergent can be achieved, simply by changing the

temperature slightly. Conventional offshore washing plants, such as those developed by Alfa Laval, can be straightforwardly adapted for use with the new detergent.

Title: Drill cuttings remediation using new microencapsulating detergents

Sponsors Confirmed: BP



Project No. : 1111 PWD AWJC ITF Funding (£k): 150 Duration (Months): 12

Summary: Objective:

- Develop an improved knowledge of cutting parameters, and the inter-relation between fluids/nozzle performance and water depth.

- Increase effectiveness of multi-tubular severance

- Increase water depth of successful cutting

- Improve cutting head performance.

- Develop a system suitable for efficient rigless well abandonment.

Title: Enhancement of Abrasive Water Jet Cutting Techniques for Well Decommissioning

Sponsors Confirmed: BP, Maersk, Shell


Summary: The Coupler development is phased over 4-phases to control costs and mitigate development risks associated with an innovative drilling technology. The first phase was

successfully completed May 2001 on time and within budget. Phases 2 (Detailed Design & Component Testing) and 3 (Prototype Manufacture) were completed during July-

August 2002. Phase 4 is divided into two work phases (Phases 4A & 4B) to mitigate risks and to prepare for a full Field Drilling Trial on an actual rig. Phase 4A (Rig Mechanical

Trial) is scheduled for July 2002- March 2003 and will also require industry support. Objectives:

1.Complete tes@ng of principal components of a Drilling Coupler and func@on test the control system.

2.Carry out a Site system Integra@on Test (SIT) and conduct a Mechanical Trial on a test rig.

3.Develop and opera@onally trial a prototype Drilling Coupler and electro-hydraulic control system.

4.Create a ‘step change’ in the way wells are constructed through increased drilling performance and development of an enabling technology for UBD, ERD, Horizontal and

HPHT drilling.

Title: Development of the continuous circulation coupler: Phase 4a

Sponsors Confirmed: BG Group, BP, Eni, Shell, Statoil, Total




Summary: In gas well management there comes a time when the flowing wellhead pressure (FWHP) falls such that economic production cannot continue. To maximise flow, some form of

compression has to be installed. Typically this is platform based and known as Central Gas Compression, but once its minimum suction pressure is reached the field has to be

abandoned leaving some ~35% of reserves un-recovered. By applying wellbore compression, as close to the formation as practicable, production can be maintained, draining

the reservoir to previously unattainable abandonment pressures. A Feasibility Study completed in 2002 showed that wellbore compression also provides exceptional production

enhancement for both new and mid-life fields, enabling operators to significantly accelerate gas production and maintain a production plateau, thereby maximising economic

returns on investment from the gas asset and production infrastructure.

Title: Downhole Compression in Natural Gas Wells, Phase 1

Sponsors Confirmed: ConocoPhillips, Eni, Husky Energy, Repsol-YPF


Summary: The Coupler development is phased over 4-phases to control costs and mitigate development risks associated with an innovative drilling technology. The first phase was

successfully completed May 2001 on time and within budget. Phases 2 (Detailed Design & Component Testing) and 3 (Prototype Manufacture) were completed during July-

August 2002. Phase 4 is divided into two work phases (Phases 4A & 4B) to mitigate risks and to prepare for a full Field Drilling Trial on an actual rig. Phase 4A (Rig Mechanical

Trial) is scheduled for July 2002- March 2003 and will also require industry support. Objectives:

1.Complete tes@ng of principal components of a Drilling Coupler and func@on test the control system.

2.Carry out a Site system Integra@on Test (SIT) and conduct a Mechanical Trial on a test rig.

3.Develop and opera@onally trial a prototype Drilling Coupler and electro-hydraulic control system.

4.Create a ‘step change’ in the way wells are constructed through increased drilling performance and development of an enabling technology for UBD, ERD, Horizontal and

HPHT drilling.

Title: Development of the Continuous Circulation Coupler-Phase 4b (Field Drilling Trial on a Land Rig)

Sponsors Confirmed: BG Group, BP, Eni, Shell, Statoil, Total



Project No. : 1300 PWD HETS ITF Funding (£k): 730 Duration (Months): 16

Summary: Well Recovery using a HETS External Patch for casing repair – Funding Proposal for ISO Qualification.

READ has successfully developed the Hydraulically Expandable Tubular System (HETS) - External Patch (EP) to provide a method of re connecting two pieces of casing downhole.

The ability to successfully connect casing downhole enables a method of replacing damaged casing, to recover a stuck casing situation or a technique for slot recovery when the

outer conductors / casings are badly corroded. HETS-EP creates a high-strength down-hole connection to deliver:

- Reliable metal-to-metal seal, life-of-well connection with high burst, collapse and mechanical ratings

- Zero ID reduction ensuring full access below the patch after well repair

- A simple connection with no seal elements, threads or moving parts

- Tough load-bearing connection tested to more than 500 tons load and 6000psi gas pressure

- Suitable for gas wells, having no elastomer seals

Specific areas of applications therefore include well recovery / integrity management in: (1) high value wells e.g. offshore deep water, subsea, HPHT, and extended reach; (2)

exploration or appraisal wells, particularly where drilling through gas; (3) well work over situations, particularly where gas production or gas injection is present; (4) slot recovery.

Currently, HETS external patches are individually designed to meet specific client requirements and once fabricated, the qualification has been unique to meet the particular

client well specification. This approach adds significantly to the lead-time and cost of supply and such qualification on a well-by-well basis is not efficient. Likewise the test

specification has been limited and in no case has the HETS-EP system been tested to its limits.

This individual qualification process has become a barrier to the implementation of this new technology. The industry will benefit from the system being qualified in accordance

with ISO test procedures. ISO standards exist to test and qualify a threaded tubular connection for tension, compression, burst and collapse. However, since the HETS-EP

connection is not a threaded connection some adaptation of existing ISO standards is required.

This proposal presents a programme of work to experimentally qualify full size HETS external patch connections (e.g. 9 5/8” L80 & P110 and 14” L80 & P110) in accordance with

an agreed set of ISO-equivalent test procedures. Furthermore, the project will develop Finite Element Analysis FEA models of the HETS-EP connection to provide correlation

between the empirical data from the tests and the analytical data from the FEA. This will effectively extend the qualification envelope both for pipe size and material increasing

the value of the test data.

This will eliminate the need to individually qualify HETS-EP on a well-by-well basis, thus permanently reducing the cost and perceived risk of deploying this new technology in the

field and improving availability.

This project will be of significant interest to well completions and intervention engineers.

Title: External Patch for Casing Repair, Industry Type Standard

Sponsors Confirmed: ConocoPhillips, Shell, Statoil




Summary: • The technology will be applied in live-well and HPHT downhole applications for visual diagnosis during the complete drilling, completion, production and work-over life cycle of

a well. Our technology will interface with generic electric line or coiled tubing equipment on the rig or platform to provide real-time visual or non-visual images downhole.

Imaging technologies used will depend on the presence of turbid fluid in the well-bore.

•

The technology presents some specific engineering challenges, and represents a significant step change in downhole diagnostics. By seeing images in real-time as they happen in

a live well situation will provide never before seen images in total wellbore diagnostics.

•

Make your decisions based on visible fact, not on unknowns.

EV Offshore’s existing drill-pipe deployed well-intervention camera has extensive history with proven reliability, high quality images and cost-effectiveness. The visual image

information that it provides the client allows critical decisions to be made that has saved operators £millions in reduced rig or non-production time and allowing decisions to be

made that reduces or removes costly downstream contingencies. It is acknowledged that wells have been suspended or abandoned due to unknown circumstances downhole,

leading to wastes time, effort and huge cost. Accurate downhole imaging has the potential to prevent this occurring.

•

The requested funding equates to approximately 36 hours rig time –this could be saved on the cameras’ first deployment.

With current rig rates between $150,000 to $450,000 depending on shallow or deep water applications, technology that has the potential to save time has a huge cost benefit.

The requested sponsor funding for the proposed technology could be recovered and justified on the first deployment of the camera.

These are typical job titles of those people who specify and use our existing technology and who have requested applications for which our new technology will be able to satisfy:

Completions Engineer;

Well Engineer/Well Operations Engineer/Wells Team Leader/Well Technology Engineer/Well Services;

Drilling engineer/supervisor/superintendent;

Reservoir Engineer;;

Petroleum Engineer;

Subsea Engineer;

Cased Hole/Logging Engineers;

Production Engineer;

Workover and Fishing Engineer;

Integrity Engineer;

Title: Real-Time Well-Intervention and Downhole HPHT Camera For Deployment on Electric-Line and Coiled Tubing

Sponsors Confirmed: ITF



Project No. : 1311 PWT ITF Funding (£k): 51 Duration (Months): 5

Summary: The Mud Watcher Continuously & In Real Time measures the Weight and Viscosity of all Drilling Fluids (Mud)

The Mud Watcher is the Core component for Mud Automation

It can be used on all wells but it would be particularly relevant to Weight Sensitive Operations e.g. HTHP Wells, Brownfield Operations or Locations with Complex Geology.

Mud Checks (Marsh Funnel & Mud Balance) are Poor Utilisation of Key & Skilled Personnel’s time (e.g. a Derrickman). Done correctly, they are Labour Intensive & Time

Consuming (analysis shows that if they are done correctly they can take upto 8 hours per 24 hours of Drilling).

As the Mud Watcher works in ’Real Time’ it will supply instant ‘Decision Making’ Data. Proper use of this Data could stop a chain of events that leads to a Lost Rig Time incidents.

Mud Watcher is Zone 1 certified.

As an example – The Mud Watcher identifies that the Mud Weight is too low & Barytes is added to bring the Mud back to specification. Without this action, Shale might have

‘sloughed’ into the hole and led to Stuck Pipe.

The Mud Watcher will Enhance Safety. This will range from Minimizing Skin to Mud contact to Operating in an Evacuated area.

As an example (of the latter) - Atmospheric H2S might be present during a ‘Kick’ and the Pit Room & Shaker House are evacuated. Knowledge of the Mud Weight during a ‘Kick’ is

Critical yet these areas (where it is normally measured) are evacuated. The Mud Watcher continues to give Real Time readings of Weight & Viscosity despite the evacuation of

the area.

Title: The Mud Watcher

Sponsors Confirmed: ConocoPhillips

Project No. : 1313 PWD SIDOX ITF Funding (£k): 44 Duration (Months): 9

Summary: The advantage of SIDOX™ is that it improves the flow of oil relative to water and thus avoids the need for handling increasing amounts of water. SIDOX™ treatment provides an

effective and consistent improvement on a continuous basis with re-treatment at 6 monthly intervals. The results suggest that Sidox™ works in fractures or voids in the

formation rather than in the rock matrix.

Title: Simulation Tests for SIDOX Inorganic Relative Permeability Modifier for Increased Oil Production

Sponsors Confirmed: BP, ITF



Project No. : 1314 PWD MAGLEV ITF Funding (£k): 220 Duration (Months): 12

Summary: Proof of Concept: To test the feasibility of using the principle of magnetic levitation in the design of a simple high power artificial lift system and build a prototype through tubing

deployed pump, that shall also form the basis for designing and building a high volume tubing mounted pump

Background: Magnetic levitation is commonly recognised in the field of high speed train development. The principles of magnetic levitation are being used in a wide range of

applications including, for instance thrusters motors on ships. Essentially magnetic levitation can be employed to impart a lateral or rotary motion to a body place within a

magnetic field. We can imagine that this method can be used to transport tools into and out of a well as well as be used as a means of activating downhole tools such as sleeves,

inflow control valves and so on.

Scope of Project: The aim of this project is to complete a proof of concept study of the use of magnetic levitation in a downhole pump, including building and testing a small

diameter through tubing deployed pump. A follow up of the project will be to commercialize such a pump solution, and then modify design and build a tubing mounted high

volume pump also. In essence the pump consists of:

1. Electromagnets located in the completion tubing powered from surface

2. Two pump pistons with built in check valves free to move along the axis defined by the electro magnets

Power on/off of the electro magnets will cause the piston to oscillate along the axis of the magnets thus creating fluid lift.

Initial discussions with companies such as SmartMotor and Siemens, who are active in this field suggest that the concept is feasible and that sufficient lift can be generated for

artificial lift applications.

Advantages of “MagLev” Pump: The major advantages of the “MagLev” pump are:

1. The conceptual design of the “MagLev” pump is very simple.

2. There are very few moving parts

3. The bulk of the pump can be retrieved from the well for servicing.

4. Full bore access into the well below the pump for logging, water shut-off, etc., is possible, as the pump can be retrieved by wireline

5. The pump will be able to lift multiphase fluids including high gas cut fluids and heavy oil.

Aim of Project: The aim of the project is to design, build and test a small scale ““MagLev”” pump for use in oil and gas applications.

Title: Retrievable Artificial Lift System Using Magnetic Levitation: Maglev Pump




Project No. : 1363 PWD PowerBall ITF Funding (£k): 420 Duration (Months): 15

Summary: In December 2007 Red Spider completed the 3 year development of a new system called the Electronic Remote Equalisation Device or eRED. This is a device which has multiple

potential applications for example, being deployed either pre-installed in a liner or completion or via intervention normally below a lock or retrievable bridge plug. The tool can

be run in the open or closed position and can then be instructed to open or close remotely from surface using a number of independent pre-programmable triggers. Depending

on the application it is possible for the open / close sequence of the eRED to be repeated multiple times. After completing an extensive test programme the eRED has been

successfully deployed in the UK and Norwegian sectors and has been received with great interest by Operators. Following the initial success of this product, we see great

potential for tubing or liner mounted version. By integrating the electronics package and associated logic from the eRED, it will be possible to provide the same functionality in

tubing / liner mounted devices coupled with a mechanical mono-bore barrier. We’ve looked at the potential market demand for such a device and see a need for a competent

alternative to the technology currently used by operators’ as part of their dual barrier policy. We believe that further development of the eRED electronics package together with

some innovative mechanical engineering solutions will result in a ‘game changing’ reservoir isolation barrier within a relatively short period of time.

The PowerBall Reservoir Isolation Barrier (RIB) provides the operator with a flexible downhole barrier incorporating a number of unique features designed to ensure reliable

operation in hostile downhole conditions.

Main value adding features are;

Ability to handle well debris settlement above the closed ball – we see this as being the normal operational environment for these tools and shouldn’t be a reason for failure to

open

Flexibility – tools can be set up on site prior to deployment taking any changes in well parameters or operational requirements into consideration. In effect one tool suits all

applications.

Primary and genuine back up opening mechanisms – working independently of each other

Any over-ride operations can be quickly functioned using wireline

The real value which PowerBall will provide to operators is a reduction in rig time and operational risk and increased operational flexibility in the field. Cost of failure in this

sector is extremely high, as are the cost of contingencies when planning for failure.

Title: Reservoir Isolation Barrier

Sponsors Confirmed: BG Group, BP, Chevron, Maersk



Project No. : 1367 PWD BPRP ITF Funding (£k): 146 Duration (Months): 15

Summary: Brinker Technology have recently completed the initial development of Platelet Technology® for well integrity applications and are working on the first live applications at

present. This development has addressed many of the issues raised in the Well Integrity Remediation Systems call for proposals. Platelets can be injected from surface into the

tubing or annulus to seal downhole leaks without the need for costly intervention.

Specific issues that have been addressed in the development are:

1. Tubing leaks

2. Annulus leaks

3. Casing leaks

4. Wellhead / tubing hanger leaks

However the technology at present cannot withstand reverse pressures which means that in certain circumstances careful annulus pressure management is needed. For

example in a tubing leak scenario if the annulus pressure exceeds the tubing pressure for some reason the Platelet® will be displaced. In addition wireline or slickline operations

would potentially displace a Platelet®.

This proposal is to develop the technology further so that an entrained Platelet® can withstand reverse pressure removing these constraints.

Title: Back Pressure Resistant Platelets®




Project No. : 1370 PWD Revolver ITF Funding (£k): 378 Duration (Months): 12

Summary: In December 2007 Red Spider completed the self funded 3 year development of a new system called the Electronic Remote Equalisation Device or eRED. This is a device which

has multiple potential applications for example, being deployed either pre-installed in a liner or completion or via intervention normally below a lock or retrievable bridge plug.

The tool can be run in the open or closed position and can then be instructed to open or close remotely from surface using a number of independent pre-programmable triggers.

Depending on the application it is possible for the open / close sequence of the eRED to be repeated multiple times. After completing an extensive test programme the eRED has

been successfully deployed in the UK and Norwegian sectors.

RollerBall & eMotion: Proposed development of 2 components to provide a packaged solution

Positive feedback from clients has identified a desire for Red Spider to develop a tubing mounted version of eRED for use in the upper completion. By integrating the electronics

and associated logic from the eRED (housed in the eMotion assembly), it will be possible to provide the same functionality but this time in a tubing mounted device (RollerBall)

thereby negating the requirement for intervention to retrieve eRED. The real value to operators is a reduction in rig time and operational risk and increased operational flexibility

in the field. When running a new completion, multiple interventions are usually required to install and then retrieve the barriers necessary to enable the drilling BOP’s to be

removed and the Xmas tree to be installed and tested safely. By placing a RollerBall (& eMotion) below the Production Packer for example, a deep set barrier is already in place

before running the completion. Likewise a RollerBall (& eMotion) installed below the Tubing Hanger provides the shallow set barrier and all wellhead and tree testing would be

carried out against it. RollerBall is opened and closed on command without the need for hydraulic control lines from surface and will normally be deployed in the open position

to enable the completion to self fill whilst running in. Several open and close commands are possible due to the use of the eRED logic in eMotion which expands the potential

applications.

In future it should be possible to adapt RollerBall for use with control lines from surface if this would be preferred – for example as a long term open and close barrier without

utilising eMotion.

The eMotion is the brains behind this package in that it converts the commands from surface into the open and close operation of RollerBall. The tool however will be adaptable

for use with other downhole systems in the future – not just with RollerBall as demonstrated here.

Title: Through Tubing Control Valve & Electronic Control Module


Project No. : 1375 PWD WISE ITF Funding (£k): 90 Duration (Months): 4

Summary: This project will carry out initial practical investigations required to enable the development of a new system for wireless communication in gas wells. The work will focus on the

provision of high data rates, low power consumption, and small size allowing flexible sensor placement. The expected benefit is identification of the properties of the in well

communication channel. The measured channel parameters can then lead to the design of an in-well communication technology that supports “smart wells” and provides better

management of gas wells, reduced maintenance requirements and lower operational costs. Roke is uniquely position to perform this work, due to our expertise and experience

in radio propagation, advanced wireless communications and wireless power distribution, which we propose to apply to the medium of gas wells. The result of the work will be

in-well communication channel parameters that can be used to develop a system concept for an in well wireless communication system that supports high data rate, two-way,

real-time telemetry with a simultaneous reduction of down-hole equipment size and power consumption, combined with a longer battery life or potential elimination of the

need for batteries.

Title: Wireless In Well Communications for Telemetry





Summary: TTP understand the current difficulties in wellbore communications using electromagnetic and acoustic techniques. Stakeholders in the industry have tried for many years to

produce reliable systems but have experienced difficulties in propagation performance through sub-surface rocks, since rocks are often conductive due to their salt and/or metal

content. Acoustic transmission through the borehole is subjected to similar problems due to the variability of the acoustic channel under different operating conditions of the

well. Some such studies and prototype systems have used older modulation and coding techniques which do not possess the ability of the modulated signal to be detected and

decoded below the noise floor.

TTP are a leading provider in technology innovation and development, with a wealth of experience in wireless communications, electronics design (including energy harvesting

techniques, acoustics and radio systems), mechanical design, piezoelectric transducers and project management.

TTP propose a feasibility study to analyse previous work done by industry stakeholders and third parties with a view to possible improvements using modern signal modulation

and coding techniques. For example, various forms of quadrature modulation, raptor codes, LDPC and Turbo codes.

Title: Future In Well Communication Techniques



Summary: This variation covers a further study into Advanced Modern Communication Techniques to Address Current Wireless Down-Hole Communication Limitations as more fully

described in the Scope of Work document reference number GB7793 (attached). This document is entitled “Schedule 1a”.

The Scope of Work covers 2 key activities:

•Acous@c Communica@ons Concept

•Fully mechanical down-hole pressure/temperature gauge

The output of the work will be:

Acoustic Communications Concept -

•a report in presenta@on format

•IP protec@on findings and recommenda@ons

Fully mechanical down-hole pressure/temperature gauge

•a report in presenta@on format

Title: Development of future in well communication techniques




Project No. : 2001 PF NEWPROCLAD ITF Funding (£k): 74 Duration (Months): 20

Summary: Damage by wear and corrosion is the main factor determining the practical life or the service interval of pumps, valves and tubular sections used in the extraction and

transportation of petroleum, gas and related products. The current option is to machine components directly from highly expensive alloys, e.g. duplex steels and nickel alloys,

but this could be replaced by using suitable surfacing processes. Current surfacing process limitations need to be overcome, and it is the purpose of this project to evaluate new

methods of depositing wear and corrosion resistant coatings onto the internal surface of tubular components, i.e:

1.Laser powder surfacing

2.Rota@onal arc spraying (thermal spraying)

3.Laser fusion of (rota@onal) arc spray coa@ngs

The proposed work has been discussed with the following companies: BP Amoco, British Gas Research and Technology Centre, Forth Tool and Valve, Fife (specialist welding and

coatings for oil and gas sector components). Comments and letters of support are included in the Appendix to this proposal

Title: New Processes for Wear and Corrosion Resistant Coatings for Internal Cladding of Small Bore Components

Sponsors Confirmed: BP, Enterprise, ExxonMobil, Marathon, Shell

Project No. : 2008 PF PIGASYS™ ITF Funding (£k): 50 Duration (Months): 6

Summary: Project PIGASYS™ is about the development and testing of a unique and autonomous traction unit for pipelines and downhole usage. The traction unit that is capable of

travelling against and with the flow of product without any external power supplied. Autonomy will enhance the range of such a tool when deployed to operate as a

maintenance-cleaning tool or as an inspection tool. A unique feature of Pigasys is its dual-purpose driving/cleaning system. The programme is set to run for approximately 12

months. Development costs to date have been shouldered solely by PACT Engineering (over £80k).

Typically the tool will save large amounts of CAPEX by removing the need for a return pigging line or a subsea pig launcher in satellite wells such as those currently operating in

the E.T.A.P. field or Central North Sea. PIGASYS™ will reduce the cost of internal pipe surveys by reducing and simplifying the inspection and auxiliary equipment.

Title: Autonomous Contra-Flow Tractor for Pipelines - Phase 1

Sponsors Confirmed: BG Group, ConocoPhillips, Hess



Project No. : 2009 PF SIFT ITF Funding (£k): 99 Duration (Months): 26

Summary:

This proposal describes a joint industry funded project which would investigate the use of system identification techniques to monitor the flow regime in offshore multiphase

production systems as a way of predicting, and ultimately avoiding through control measures, the onset of severe slugging. This Phase 1 programme would be part experimental,

part analytical, building upon the experience gained from previous research carried out for BP Amoco. The experimental work would be carried out on the BG Technology “PIPER”

two phase test rig at Loughborough. In preparation for a subsequent field trial phase (Phase 2), the work would conclude with an analysis of system identification techniques

applied to recorded field data from a riser system where severe slugging has proved problematic. Ultimately, it is envisaged that a flow regime monitoring system could be used

offshore either as a stand-alone advisor to operators, as part of a wider virtual production system simulator which could be used for optimisation of recovery, or as part of a

control system for ameliorating or eliminating slugging problems.

Title: System Identification for Flow Regime Tracking

Sponsors Confirmed: BG Group, BP, ExxonMobil, Hess, Marathon, Shell

Project No. : 2013 PF EPRIS ITF Funding (£k): 620 Duration (Months): 31

Summary: EPRIS is the development of a novel pipeline intervention system. Applications include ‘Tie-ins’ to existing pipelines and emergency repairs. Strengths include diverless

deployment & operation, and a complete ‘solution’ for pipeline intervention, without depressurising, draining or flooding the pipeline. It has great advantages over existing

systems because of its compactness, lightweight, ease of deployment, and it can be applied to pipelines which are not piggable due to pipeline damage. Phase 3 takes the

development up to ‘proof of concept’.

Title: EPRIS – Pipeline Intervention Project Phase 3


Project No. : 2020 PF Sand Coanda ITF Funding (£k): 161 Duration (Months): 12

Summary: The UKCS offshore operators are seeing increasing sand production. This is causing a rise in the number of problems seen in the production facilities, principally starting in the

separators. The most common method of handling sand is by the use of sand jetting in the separators. This is not ideal since sand jetting is a batch operation that allows sand

and solids to deposit within the vessel, causing loss of residence time. By its nature, jetting is a pressurised and turbulent activity, that may produce concentrated sand/water

slurry. This causes erosion of vessels, production upsets, poor control and most importantly, loss of production capacity, along with environmental and safety problems.

This proposal is for an on-line continuous system based upon the Zeta Linear Coanda technology that should overcome these problems and could also help provide preliminary

oily sand clean up. Preliminary studies have proved sufficiently positive to justify this work and establish a need for the system

Title: Sand moving using the Zeta Linear Coanda Unit

Sponsors Confirmed: BP, Chevron, Hess, Maersk



Project No. : 2029 PF SBC ITF Funding (£k): 320 Duration (Months): 24

Summary: The scenario is the need to restore the original environmental condition of the marine sites, involved in the search, production and transportation of hydrocarbons "Offshore".

The art.5 of the Convention of Geneva for the continental shelf quotes: "Any installations which are abandoned or disused must be entirely removed", being the objective of the

“Offshore” legislation in force the "non interference" of the offshore activities with the natural resources of the marine habitat and the use of clean technologies with no risks for

the Marine Habitat. The European Countries involved in offshore decommissioning have defined in 1 to 5 m below the seabed soil the depth for removal of the sub-sea

structures like jacket legs/piles and wellheads. The conventional technologies like explosives and high-pressure water-abrasive systems involve the use and the discharge at sea

of dangerous materials and substances. The SBC is the further development of the well-experienced patented Diamond Wire Cutting System (DWCS) designed and successfully

used by TECNOSPAMEC since 1991. Standard DWCS Machines are currently used to cut platform legs, bracings, risers/conductors or other members but in many cases

excavations are needed to reach the cutting elevation below seabed

Title: Diamond Wire Sub Bottom Cutter

Sponsors Confirmed: BP, Hess, Shell, Total

Project No. : 2032 PF PWPU ITF Funding (£k): 320 Duration (Months): 24

Summary: The purpose of this project is to develop existing technology that removes hydrocarbon contamination form waste streams to meet the requirements of the offshore industry

and new legislation planned for 2001. The further development is aimed at producing a product that can be installed downstream of existing produced water clean-up

equipment to enable hydrocarbon-in-water removal. The current North Sea standard is 40ppm and the principal aim of this project will be to reduce that to less than 30ppm.

The work will involve the application of proven technology by addressing special needs of the oil industry, the development of design specifications, the building and testing of a

pilot unit, and safety studies into application offshore. The project will deliver full functional design specifications for a unit to meet offshore and new legislative needs for

cleaner produced water discharge.

Title: Produced Water Polishing Unit, Development Study

Sponsors Confirmed: BP, ConocoPhillips, Enterprise, Maersk, Marathon, Shell, Talisman, Total



Project No. : 2035 PF CHARMVAL ITF Funding (£k): 200 Duration (Months): 24

Summary: Concern over adverse biological effects that oilfield chemicals discharged to the marine environment in produced water may produce in marine organisms has resulted in

restrictions or bans on the use of a number of oilfield chemical constituents of proven efficacy, including aromatic solvents and a number of widely used demulsifier chemistries.

Further restrictions are likely to result from the introduction of the OSPAR Harmonised Mandatory Control Scheme in January 2001 which will regulate oilfield chemical usage

offshore using hazard quotients calculated by the European Chemical Hazard Assessment and Risk Management Model (CHARM). This proposal aims through a field and

laboratory study of oilfield chemical partitioning to: validate the CHARM predictions of produced water discharge concentrations of oilfield chemical residues; provide an

increased number of default values for fraction released of surface active chemistries; and confirm whether chemicals whose usage is already restricted or banned are actually

discharged with the produced water.

Title: Chemical Discharges – Field Validation of CHARM Predictions

Sponsors Confirmed: Baker Petrolite, Chevron, DTI, Dynea Oil Field Chemicals UK, Enterprise, Huntsman, Ondeo Nalco, Shell, Statoil, The Institute of Petroleum, TR Oil Services

Project No. : 2037 PF TSA ITF Funding (£k): 93 Duration (Months): 24

Summary: Thermally sprayed aluminium (TSA) coatings are widely specified for protection of steel structures and components against saline corrosion, but there is increasing industrial

requirement to extend its application to very severe environments including deep water, and to reduce the cost for existing applications. The objective of the project is to

develop improved TSA coatings through evaluation and validation of recently developed thermal spray equipment and sealant compositions. Benefits will include improved

coatings, reduced application and maintenance costs, and a reduction in the operator exposure to respirable fume and the risk of fire or explosion from residual fine metal dust.

Title: Improving the Reliability and Cost Performance of Thermally Sprayed Aluminium Coatings

Sponsors Confirmed: BP, ExxonMobil, Halliburton, Marathon, Petrobras

Project No. : 2047 PF PIPE-AIMS ITF Funding (£k): 250 Duration (Months): 18

Summary: This proposal details the development of a fully validated, low cost pipeline condition monitoring system, known as the SAAM™ D6.0. The proposal builds on work carried out

over the past 6 years by RST Projects Limited, on previous versions of the SAAM™ pipeline inspection tool. The developed monitoring system will make use of technologies

which can be deployed onboard routine cleaning pigs. It will be capable of detecting and monitoring typical pipeline defects such as corrosion, mechanical damage and pipeline

out-of-straightness.

Title: SAAM™ D6.0 - Pipeline Asset Integrity Management System

Sponsors Confirmed: BP, Chevron, Enterprise, Maersk, Marathon, Shell, Total, Veba



Project No. : 2065 PF HYPER ITF Funding (£k): 120 Duration (Months): 24

Summary: Advantica has been combining its laboratory studies on hydrates and pipeline simulation expertise to validate models to predict hydrate formation in offshore pipelines for a

number of years. We now propose to use this approach to develop a new software tool, compatible with industry standard simulators such as HYSYS, to indicate:

How much hydrate could form in an offshore pipeline

Whether this hydrate will cause a blockage and a loss of produc@on.

If successful, this approach could reduce conventional hydrate treatment costs to a third of their present levels, without any adverse effect on production.

Title: A New Design Tool to Prevent Production Losses due to Hydrate Pipeline Blockages

Sponsors Confirmed: BG Group, ConocoPhillips, Halliburton, Marathon

Project No. : 2070 PF SPACE AGE ITF Funding (£k): 163 Duration (Months): 9

Summary: The oil industry has been seeking alternatives to the use of umbilicals for at least ten years. However, the services provided must be replaced. All of these require power. Thus,

to move towards umbilical-less systems, some form of subsea power generation is required. However, it must be integrated with other components in order to offer a fully-

functional system solution. This proposed work programme examines a number of options for subsea power generation, produces plans for their future development and

eventual deployment and identifies other areas and components that will be needed to make alternative solutions viable, both technically and commercially. It has been

prepared at the request of ITF and its member companies in order to provide an independently co-ordinated approach to progress a number of the individual proposals that

were received in response to the ITF “Call for Proposals: Subsea Power Generation” published in November 2000.

Title: Subsea Power – A Comparative Evaluation of the Applicability of Generation Equipment

Sponsors Confirmed: ConocoPhillips, Hess, Shell

Project No. : 2073 PF ITF Funding (£k): 100 Duration (Months): 12

Summary: The UKCS offshore operators are seeing increasing sand production due to often aging fields. This is causing a rise in the number of problems seen in the production facilities,

principally starting in the separators. Rather than the current typical methods of trying to control and remove sand when it is in the separators, this proposal is for a pre-

separation system that intercepts bulk sand before reaching the production separation systems. It is a new concept passive system that is continuously on line and forms part of

the piping system between the manifolds and the separators.

In simple terms, a combination of pipeline geometry and use of Zeta’s ZVE vane technology accelerates particle deposition into a “sump”. Emptying of the sump, although

involving a difficult HP / LP interface, could be achieved by the existing Merpro TORE technology.

Title: Sand Precipitation Using the Zeta Sand Fairy

Sponsors Confirmed: BP, Chevron, Statoil



Project No. : 2088 PF WELDCLAMP ITF Funding (£k): 103 Duration (Months): 12

Summary: The performance of friction or adhesive clamps for jacket repairs is impossible to monitor during service. Repairs by dry habitat welding are extremely expensive and require

diver welders. These problems can be overcome by welding repair clamps directly in water. Recent advances in wet underwater Friction Stitch Welding will permit the

development of a low cost underwater welded clamp systems. Friction welding has a much less severe thermal cycle than arc welding underwater so high harness values are

generally not a problem. With Friction welding there is no electric arc to evolve hydrogen and this solid phase process is not sensitive to increased water depth. Friction Stitch

Welding is a mechanised process and can be done without divers. Welded clamps will provide greater structural integrity and reduce long term inspection costs. This in-water

welding processes will be evaluated against current offshore codes and standards. Welding procedures will be developed for clamp repairs on jackets and the welds tested.

Methods of deploying the welding equipment will be proposed and suitable inspection systems evaluated. A later phase of the project would deal with a full scale

demonstration.

Title: Low Cost Underwater Friction Welded Jacket Repair

Sponsors Confirmed: BP, Shell, Stolt Offshore

Project No. : 2106 PF Teletest ITF Funding (£k): 100 Duration (Months): 6

Summary: Removing insulation from pipework or vessels for 100% inspection is time consuming and costly. Improved methods for inspection under insulation, both in and out of service,

are needed. Long range ultrasonic testing is proven for ambient temperature inspection under insulation of onshore pipework. However, It has been targeted on long straight

sections of pipe unlike the more complex geometries often found offshore. Furthermore, the current tooling has a maximum temperature capability of +125ºC, whist offshore

pipework can go up to +150ºC.

This proposal tailors the current system to test all key offshore facilities at ambient temperatures and then further modifies the tooling for durability and ease of handling when

hot.

Title: Inspection Underneath Thick Insulation

Sponsors Confirmed: BP, Enterprise, Hess, Shell



Project No. : 2145 PF SAFEBUCK ITF Funding (£k): 325 Duration (Months): 18

Summary: Subsea pipelines are increasingly being required to operate at high temperatures and pressures that result in significant axial compressive loads in the pipe. This is a particular

problem for pipelines that are heavily insulated to maintain production fluid temperatures. Increasingly expensive solutions are being adopted, such as burial or intermediate

expansion spools, to control or relieve axial compression. A more efficient solution is to relieve the axial stress by the controlled formation of buckles along the flowline length.

A lateral buckling design guideline and the proposed testing program will significantly raise confidence in this design approach and provide a more elegant and more cost

effective solution on future projects. This JIP will: produce design guidelines for on-bottom lateral buckling of pipelines; Develop predictive models for the behaviour of on-

bottom lateral buckling pipelines; Develop innovative methods for initiating and controlling lateral buckling; investigate the integrity of flowline joints subjected to bending loads

in excess of SMYS and subsequent cyclic stress at high temperature; and Investigate pipe-soil interaction for large cyclic displacements including soil-berm development, with full-

scale tests.

Title: Safe Design of Hot On-Bottom Pipelines with Lateral Buckling

Sponsors Confirmed: Allseas, BP, ConocoPhillips, ExxonMobil, NKK/Mitsubishi, Petrobras, Shell, Tenaris

Project No. : 2168 PF SPI-NAV ITF Funding (£k): 224 Duration (Months): 12

Summary: Inspection of risers for fatigue damage caused by vortex induced vibration is currently carried out by ROVs equipped with ac impedance sensors. The method is laborious for the

pilot, can only be carried out in conditions of good visibility, and generally involves the expense of a surface support vessel. An Autonomous Underwater Vehicle (AUV) equipped

with appropriate sensing and deployed from an FPSO would reduce cost (no surface support vessel), and can work in low/zero visibility conditions when equipped with newly

available acoustic and NDT sensors.

The project will demonstrate use of an Autonomous Underwater Vehicle to (AUV) to automatically inspect a riser. Newly developed on-vehicle sensors will be used to track the

riser, automatically manoeuvring the AUV to provide complete inspection coverage. The use of novel sensors and intelligent systems will be investigated to autonomously detect

and locate riser failure points. Advanced visualisation methods, including sensor data mosaicing, will be used to provide useful data output for client records,

Tank demonstrations will be provided using the RAUVER testbed AUV equipped with necessary intelligent systems and sensors, leveraging developments in recently completed

and ongoing EU, BP and US Navy sponsored projects in AUV pipeline inspection, docking, NDT sensor development and mine countermeasures.

Title: Subsea Planned INspection with an Autonomous Vehicle

Sponsors Confirmed: BP, ConocoPhillips, DTI, Subsea 7



Project No. : 2173 PF CLIP ITF Funding (£k): 300 Duration (Months): 18

Summary: Upstream oil and gas pipelines have to transport aggressive produced hydrocarbons. There are a number of ways the industry deals with these aggressive hydrocarbons

including; use of expensive corrosion resistant alloys, engineering extra thickness into normal steel pipes to allow for corrosion (a “corrosion allowance”) and the use of corrosion

inhibitors. Pipelines also suffer from deposition of wax and hydrates from the produced hydrocarbons which has a negative effect on the flow of hydrocarbons.

The use of suitable liners inside pipelines could alleviate all of the above “problems”. Composite liners of the sort described in this proposal would allow the use of “normal”

steel instead of more expensive exotic, corrosion resisting steels. Composite liners would allow pipelines to be built to requirement, rather than having to engineer extra

“allowances” to deal with corrosion and also negate the requirement for dosage of production corrosion inhibitors. Added benefit would be reaped in terms of insulation of the

metallic pipe (a novel insulation method is outlined in this proposal) and the hydrocarbon (insulation would reduce the temperature changes seen by the metal pipe, thus

limiting pipeline expansion and potentially buckling issues. Insulation would also reduce the temperature drop of the produced hydrocarbon and therefore reduce the chance of

produced hydrocarbons reaching the wax appearance temperature) and also reduced wax / hydrate deposition due to the low energy surface of the liners. The major issue with

use of liners is collapse under depressurisation conditions. Use of composite liners as described would resolve this issue through the liners inherent strength (resistance to

collapse) and also through use of alternative solutions venting solutions.

This proposal uses a unique liner technology which has been proven in the water industry.

The proposed workscope will deliver:

•A mul@-func@onal thermoplas@c composite liner exhibi@ng the following characteris@cs:

Excellent chemical corrosion resistance

Inherent oil/gas permeation resistance

Low wax/hydrate deposition

Improved flow (i.e. reduced drag)

Structural strength – capable of withstanding internal and external forces

Thin walled (2-3mm thick for 200mm diameter pipe)

Thermally insulating

•Dynamic in-situ lining process and associated equipment capable of lining pipes at rates of up to 1 metre / min.

•Literature review and techno-economic comparison of Euro-Projects (LTTC) Ltd.’s thermoplas@c composite liner and current lining systems

•A report on long term ageing and performance of thermoplas@c composite liners

Initial market testing has shown great interest already from one supermajor and two key subsea contractors

Contd…

Title: Advance Composite Liners In Pipelines for improved flow assurance and pipeline integrity

Sponsors Confirmed: Chevron, DTI, Hess, Saint Gobain, Stolt Offshore, Subsea 7



The JIP contractors will be Euro-Projects (LTTC) Ltd., Newcastle University and OTM consulting.

Euro-Projects (LTTC) Ltd. has considerable experience in managing major UK, European and international projects from concept to market. Euro-Projects (LTTC) Ltd. has

specialised over the last 10 years on thermoplastic composites technology with several patents in this field. Euro-Projects are the concept and product originators and have

several years experience in using and adapting this material to uses such as roadside lighting piles to low weight concrete reinforcement piles for use in strengthening concrete

structures without suffering the corrosive disadvantages of steel.

Newcastle University has worked extensively on non metallic pipes and have at their disposal extensive test facilities which will be used for this project.

OTM Consulting Ltd. are the project managers for this JIP. We have significant experience of launching and managing JIP’s as well as operating in strategic and knowledge

management areas for the upstream oil and gas industry.

The test programme will require £300K funding (6 operator equivalents at £50K each, contractors at £25K) and will take place over 18 months.

Project No. : 2187 PF FA2M-LDHI ITF Funding (£k): 150 Duration (Months): 36

Summary: The objective is to study the mechanisms of inhibition offered by Low Dosage Hydrate Inhibitors (LDHIs) and improve their performance by better design and/or deployment

procedures. A novel experimental technique based on visual observation capabilities of a high-pressure (400 bar) glass micromodel will be employed to analyse gas hydrate

nucleation and growth in the presence and absence of LDHIs. The tests will be repeated in a high-pressure (700 bar) kinetic rig to examine repeatability and up-scaling of the

information generated in the glass-micromodel set-up. Various fluid systems, including; THF, methane, CO2, natural gas, gas condensate and oil will be tested to examine the

effect of various parameters on the performance of LDHIs.

The impact of various parameters, including; degree of subcooling, salinity of produced water will be investigated. A minimum of 10 LDHIs, after consultation with the

sponsors, will be selected for the study. Furthermore, the glass micromodel will be used to generate data on hydrate particle size distribution in the presence and absence of

LDHI.

The performance of the LDHIs will then be tested in a high-pressure (700 bar) kinetic rig set-up to examine the validity and repeatability of the results obtained in the glass

micromodel tests. The data generated in the glass micromodel and the kinetic rig will be used to design new formulations and/or deployment procedures.

Title: Flow Assurance: Micro and Macro-Scale Evaluation of Low Dosage Hydrate Inhibitors

Sponsors Confirmed: BP, Total




Summary: In the last year several offshore assets that utilise flexible risers for gas export have experienced high levels of piping noise and vibration. These levels of excitation have led to

two piping failures that resulted in releases of hydrocarbon gas. The problem has been attributed to a vortex shedding phenomena within the riser.

As the dry gas passes over the internal corrugations of the flexible riser carcass, vortex shedding occurs. If this effect is coupled with a pipework acoustic resonance the effect is

to generate very high internal dynamic pressure levels. These pressure fluctuations have the potential to cause small-bore connection failures on the topside and subsea

pipework associated with the riser. Consequently, operators become limited on the maximum flow rate that may be safely passed through the riser, which in turn limits

production capability.

As the demand for gas export from deepwater fields is increasing, the likelihood of many more assets experiencing the same problems is high.

Title: Flow Induced Fluctuations in Flexible Risers

Sponsors Confirmed: BP, ExxonMobil, Statoil

Project No. : 2226 PF Pigasys™ ITF Funding (£k): 290 Duration (Months): 18

Summary: The PIGASYS™ development project concerns the design, manufacture, and testing of an internal traction unit for pipelines that is capable of travelling against and/or with the

flow of product without any external power supply. The device, operates as a wax build up prevention tool and/or maintenance-cleaning tool or as an inspection tool. A unique

feature of Pigasys is its dual-purpose driving/cleaning system. The tool develops its own traction by drawing power from the fluid flow and will incorporate fail-safe mechanisms

to return it to its point of launch or a safe site in case of any obstruction to its operations. Pigasys is also capable of varying its speed so as to allow investigation of particular

trouble spots in a line. Stage I of its development, now complete has proven the viability of the basic design and lays the path for Stage II. The tool has potential to provide large

cost savings in CAPEX by removing the need for a return pigging line or a subsea pig launcher to satellite wells. Opex savings mainly in the form of deferred production and the

reduction in use of wax inhibitors are also available.

Title: Pre- Production Prototype Stage II (Autonomous Contra-flow Tractor for Pipelines)

Sponsors Confirmed: CNR, ConocoPhillips, Eni, Hess, Petro-Canada, Scottish Executive




Summary: As the industry faces ever more production water and increasingly stringent regulation on the discharge of produced water, correct analysis of oil-in-water becomes more

important both for the regulators and offshore operators. A new ISO Standard was introduced for the analysis of Oil-in-Water using Gas Chromatography and Flame Ionisation

Detection (GC-FID), which has so far proved inadequate for the analysis of oil in produced water that is derived from gas/condensate installations. A new method using

Supercritical Fluid Extraction and Infrared (SFE-IR) has recently been established and has demonstrated great potential in replacing the old Infrared method that uses Freon. SFE-

IR has focused mainly on onshore applications therefor there is a need to prove that the method is suitable for analysing produced water oil content (crude oils and

condensate). The proposed project will compare the performance of SFE-IR against the old approved IR method and will investigate and identify what is needed to make it

suitable for offshore oil content analysis applications.

Title: Testing & Evaluation of the Supercritical Fluid Extraction and Infrared Oil-in-Water Analysis Method

Sponsors Confirmed: BP, DTI, Statoil


Summary: OSPAR strategies require that monitoring data are available in order to establish the environmental impact of offshore oil and gas activities. The largest discharge from these

activities is produced water (PW). The aims of this proposal are to inform and focus monitoring plans and risk assessment procedures through the identification of biologically

active substances present in PW discharges. This will be achieved by using toxicity identification evaluation (TIE) procedures.

Title: Characterisation of Persistent, Bioaccumulative and Toxic Chemicals in Produced Water Discharges

Sponsors Confirmed: DEFRA, DTI, Shell, UKOOA

Project No. : 2234 PF MSIEVE ITF Funding (£k): 72 Duration (Months): 6

Summary: Two key novel aspects are: surface microfilter membranes with high flux/fouling resistance and high shear at the membrane surface produced by controlled oscillatory motion.

The oscillation generates high shear, much greater than during crossflow filtration, and recycling of the feed suspension is not required. Thus, very high water recovery rates are

possible whilst the mechanically derived shear maintains high filtration rates on the novel microfiltration media. This results in compact and light equipment for the filtration of

suspended solids and oil drops. Data on SDI values with suspended solid and oil content will be generated, to assist in design calculations.

Title: Micro-sieving of seawater and produced water for oil and solids removal

Sponsors Confirmed: Eni, Shell, Statoil




Summary: This proposal addresses developing a biologically meaningful method of estimating and measuring the effects of man-made noise. The proposal addresses behavioural effects,

which occur at much lower levels than physical effects such as death or injury, can occur at large distances from the source, and hence can potentially effect large numbers of

individuals.

Estimating the effects of noise requires a perception scale which includes the species’ frequency range and sensitivity to underwater noise. We propose refining and validating a

scale proposed by the authors for measuring the perceived level of noise (the dBht(Species)), by analysis of the large body of measurements available to the authors, initial

ground truthing on simple biological models and the provision of “species sound level meters” allowing existing observations of, and proposed experiments on, marine mammal

behaviour at sea to be related to a biologically meaningful measurement of noise.

Title: Estimating the environmental effects of man made noise

Sponsors Confirmed: Chevron, DTI, Shell, Total

Project No. : 2309 PF AquaPurge™ ITF Funding (£k): 160 Duration (Months): 12

Summary: Following the successful JIP in 2 phases of the AquaPurge™ System development, a 3rd development phase of work is proposed. Phase 1 proved the overall concept; Phase 2

developed key issues regarding equipment scaling and offshore adaptation. Phase 3 will consolidate work done Phases 1 and 2, to establish links between levels of Ozone

required to treat various situations. Also, Phase 3 will optimise the mixing systems, reducing inlet pressure requirements; improve turndown and equipment flexibility, and

resolve issues surrounding higher temperature and pressure applications. To succeed here, the current offshore equipment will be modified to meet a range of operating

parameters with a view of conducting 4 – 6 offshore trials of about 1 month duration on different facilities.

Following completion of trials, data can be assessed and optimisation of equipment completed. The overall programme is scheduled to run for about 12 months based on a 1

month trial and 1 month assessment / set up process for next trial.

Title: Optimisation of AquaPurge™ Produced Water Polishing Unit

Sponsors Confirmed: Chevron, ConocoPhillips, Shell, Total



Project No. : 2311 PF Bubbletherm ITF Funding (£k): 200 Duration (Months): 12

Summary: Development of a thermal insulation system for submarine pipelines utilising shrouded and compartmentalised proprietary lightweight low thermal conductivity material,

typically 0.045 W/m K. The system will be configured to have the ability to be installed and operated at down to a target depth of circa 2000 metres. Calculations indicate that

‘U’ values of less than 1.0 W/m2 K are possible. System is termed a ‘Wet System, i.e. non pipe-in-pipe. It is also aimed at obviating for most installation methods, the need for

complex field joints and to derive other cost reducing / logistical benefits. A further foreseen advantage of the system, is that it may be possible to relatively easily incorporate

an active system, such as electrical trace heating. While the system features radically new design concepts, it is considered that it is not so radical such that the naturally

cautious Oil & Gas industry will be able to accept it.

Title: High performance Non Pipe-in-Pipe Thermal Insulation System

Sponsors Confirmed: BG Group, BP, Shell, Total

Project No. : 2329 PF PIGASYS™ ITF Funding (£k): 280 Duration (Months): 6

Summary: The PIGASYS™ development project concerns the design, manufacture, and testing of an internal traction unit for pipelines that is capable of travelling against and/or with the

flow of product without any external power supply. The device, operates as a wax build up prevention tool and/or maintenance-cleaning tool or as an inspection tool. A unique

feature of Pigasys is its dual-purpose driving/cleaning system. The tool develops its own traction by drawing power from the fluid flow and will incorporate fail-safe mechanisms

to return it to its point of launch or a safe site in case of any obstruction to its operations. Pigasys is also capable of varying its speed and distance so as to allow investigation of

particular trouble spots in a line.

Title: Autonomous Contra-flow Tractor for Pipelines- Phase 2b

Sponsors Confirmed: CNR, ConocoPhillips, Eni, Petro-Canada

Project No. : 2337 PF OIWAM ITF Funding (£k): 75 Duration (Months): 12

Summary: The recent agreement to adopt a new reference method based on Gas Chromatography and Flame Ionisation Detection (GC-FID) for the analysis of oil-in-water by January 2007

presents some significant challenges for both operators and regulators. In order to facilitate a smooth transition from the current Infrared (IR) based method the new method,

NEL in partnership with the DTI is proposing this Joint Industry Project (JIP) on “Oil-in-Water Analysis Method (OIWAM)” aiming at:

- Identifying the best practical means to implement the new reference method

- Establishing best practice guidelines for oil-in-water sample taking and handling

- Developing a realistic set of acceptance criteria for alternative analysis methods

- Advising on how to relate results from the new reference method, and alternative methods to the current IR method

Title: Guidelines for Application of New Reference Oil-in-Water Analysis Method

Sponsors Confirmed: BHP Billiton, Chevron, CNR, Maersk, Marathon, Shell



Project No. : 3001 PSD AUTO-ED ITF Funding (£k): 93 Duration (Months): 12

Summary: The project proposes to develop a software tool for combining four key interpretive methods to resolve boundary, edge, depth and surface information from gravity and

magnetic data.

The tool will be applicable to the newly available observed gravity gradient data which is currently not well understood partly through lack of appropriate interpretive tools. It

will also be applicable to observed magnetic gradient data and conventional scalar gravity and magnetic data.

Title: Automated Boundaries, Edges, Depths and Surfaces from Gravity and Magnetic Data

Sponsors Confirmed: ConocoPhillips, DTI, Shell, Statoil, Total

Project No. : 3002 PSD 4DG ITF Funding (£k): 150 Duration (Months): 22

Summary: In 1999 ARK Geophysics completed a study on the application of gravity methods to reservoir monitoring - funded under the Pathfinder Scheme. The results of this theoretical

study were encouraging in that existing gravity instrumentation could be used in an onshore setting to detect the movement of an oil or gas and water interface moving through

a reservoir.

This proposal is to undertake a field trial of the method over an onshore oil or gas field. This will involve an initial ‘forward modelling’ phase to establish potential changes,

followed by the establishment of a high spatial resolution gravity network for repeat measurements to allow the technical and commercial feasibility of the method to be fully

explored.

Title: 4D Gravity Onshore Field Trial

Sponsors Confirmed: Shell, Statoil, Total

Project No. : 3004 PSD AVOSS ITF Funding (£k): 150 Duration (Months): 36

Summary: This proposal is to seek financial support for a collaborative project between the University of Strathclyde ("Strathclyde") and Gravitec Instruments Limited ("Gravitec"), for the

evaluation, testing and development of Gravitec’s string-sensor gravity gradiometer for oil, gas and mineral exploration. It is believed that the sensor has the potential to deliver

high resolution gravity gradient data from a mobile platform and as such will have multiple applications in the oil and gas industry.

The project encompasses a two year testing and development programme and a third year of field trials to enable the technology to be transferred to the commercial sector.

The project has been costed at £1.45 million with a phased funding requirement of £150,000 from commencement to Milestone 1, £450,000 from Milestone 1 to Milestone 2

and £850,000 from Milestone 2 to Milestone 3.

Title: Evaluation, Testing, and Development of a String-Sensor Gravity Gradiometer for Oil and Gas Exploration

Sponsors Confirmed: NIMA, Western Mining



Project No. : 3005 PSD PEGASUS II ITF Funding (£k): 715 Duration (Months): 36

Summary: The PEGASUS II project is a continuation of a managed project originally funded by EPSRC (MTD) and industry from 1996-1999. A well-integrated and well-established team of

researchers from four universities and five service companies will work together to improve the scientific understanding of the fundamental properties of petroleum reservoirs.

The aim of the consortium is to develop a more scientific, systematic and cost-effective approach to the measurement of reservoir properties, from the laboratory to their

prediction in hydrocarbon fields. The project will do this by adding to a very well characterised data set, both in terms of geological description and the range and quality of

measurement of physical properties under a variety of laboratory and field conditions, making this available to industry through web-based technology.

To our knowledge, there is no other integrated project of this type in the world. Amongst the international petrophysical community, the PEGASUS team is well respected as

providing leading-edge research, particularly using this integrated approach. The involvement of service companies in the project will ensure rapid exploitation of the results by

the UK service sector.

Title: The scientific development of relevant and cost effective petrophysical methodologies

Sponsors Confirmed: BG Group, EPSRC, Halliburton, Hess, Robertson Research, Schlumberger

Project No. : 3016 PSX ITF Funding (£k): 15 Duration (Months): 9

Summary: The purpose of this study is to allow Soundmotion to investigate the suitability of the KIA algorithm to a number of seismic signals processing issues. During the study

Soundmotion will develop their understanding of the seismic world and interact with ITF’s clients to investigate the particular problems as set out in section AA of this document.

Soundmotion will endeavour to analyse any new problems and sub-problems as they arise.

Title: Applying Novel Pattern Recognition Techniques to Seismic Data Processing

Sponsors Confirmed: BG Group, BP, Chevron, ConocoPhillips, ITF

Project No. : 3020 PSD ISSSA ITF Funding (£k): 383 Duration (Months): 36

Summary: We have developed an intelligent interpolator, designed to solve an analogous problem, that is able to learn how to predict missing seismic traces using existing data provided

that certain simple conditions are met. Initial testing has shown that this scheme can predict pre-stack seismic data, over large trace separations, with minimal error. We

propose to develop this technology such that, when coupled with modified acquisition geometry in the field, it allows a significant reduction in field effort and consequent cost,

while simultaneously enhancing data quality in terms of fold of cover, azimuthal and offset coverage and consistency. The scheme has applications in all forms of seismic

acquisition, but is most readily adaptable to marine multi-streamer 3D acquisition, and is especially relevant when this forms part of a 4D time-lapse survey.

Title: Interpolated Sparsely Sampled Seismic Acquisition

Sponsors Confirmed: BG Group, BP, Chevron, DTI, Hess, Maersk, Shell, Total



Project No. : 3025 PSD ITF Funding (£k): 360 Duration (Months): 24

Summary: The objective of this project is to develop practical methods for rapid history matching of reservoir models using repeated time-lapse seismic data. In particular, it addresses the

need to reduce turnaround time between acquiring each seismic survey and evaluating its impact on the decision to update and manage the reservoir model. The project

supports the emerging trends in 4D usage through the development of relevant methodology, software and workflows.

Title: Practical Dynamic Updating of Reservoir Models Using Frequently Acquired 4D Seismic Data

Sponsors Confirmed: BG Group, BP, Chevron, DTI, Hess, Maersk, Shell, Total

Project No. : 3041 PSD SAIL ITF Funding (£k): 360 Duration (Months): 42

Summary: Improvements in data acquisition have made it possible to detect seismic anisotropy in hydrocarbon environments and newly developed anisotropic processing techniques lead

to more accurate images of the sub-surface. However, the anisotropy in itself holds valuable information about rock properties and, as such, can be viewed as a seismic

attribute. The aim of this project is to quantify the styles of anisotropy in a range of lithologies such that seismic measurements of anisotropy can be used to characterise

lithologies and fluid properties. The relative roles of fracture induced anisotropy versus more intrinsic anisotropy due to preferred orientations in crystals and grains in a given

rock type will be investigated. The strength of our approach is that is links analysis of core and seismic data from a range of hydrocarbon settings. State-of-the-art techniques for

estimating crystal, grain and fracture orientation in deformed synthetic and natural samples and inverting seismic data for anisotropy parameters will be used. Upscaling seismic

properties from core to seismic surveys will be a central issue in this work.

Title: Seismic Anisotropy as an Indicator of Lithology and Fluid Properties

Sponsors Confirmed: BG Group, BP, Chevron, DTI, Enterprise, Hess, Maersk, Shell, Total

Project No. : 3044 PSD CSHI ITF Funding (£k): 326 Duration (Months): 36

Summary: Seismic data is increasing in quality and finds ever greater use in both exploration and reservoir monitoring. With time-lapse monitoring, detection of subtle changes is possible.

The need to understand the seismic response to pore fluid properties and changes and altering environmental conditions (mostly pressure) is critical. Currently, translation of

seismic data into useful engineering parameters such as hydrocarbon type, saturations, or effective pressure is qualitative at best.

Important factors such as velocity dispersion, fluid property variations, and rock-fluid interactions are not taken into account.

We propose to measure a suite of samples from specific reservoir intervals both ultrasonically and at seismic frequencies. These data will be combined with well logs to derive

fluid substitution effects and predict and constrain possible seismic attributes related to pore fluids and reservoir characteristics.

Title: Calibrated Seismic Hydrocarbon Indicators

Sponsors Confirmed: BG Group, BP, Chevron, Hess, Maersk, Shell, Total



Project No. : 3062 PSD ISF ITF Funding (£k): 706 Duration (Months): 36

Summary: Methods for improved simulation and characterisation of fractured and faulted reservoirs will be developed. A state-of-the-art finite-element code will be optimized for the

simulation of multiphase flow and deformation for reservoir models with discrete fracture representations. Novel techniques for generating unstructured grids, solving the

governing equations and transporting fluid will be applied. Geologically realistic models of a range of common fault and fracture geometries will be used to compute

appropriate upscaled flow parameters for full-field simulation. These average properties will be used in a commercially available streamline-based simulator with a generalized

dual porosity formulation. All upscaled properties, such as matrix-fracture transfer, will be based on physically and geologically realistic fracture simulations. The different

simulation approaches will be compared with each other and to conventional simulation results to validate the approach.

Title: Improved Simulation of Fractured and Faulted Reservoirs

Sponsors Confirmed: BG Group, BP, ConocoPhillips, DTI, Enterprise, Hess, Maersk, Petro-Canada, Shell, Statoil, Total

Project No. : 3066 PSD BMFFFS ITF Funding (£k): 750 Duration (Months): 36

Summary: This three-year project will develop a process-based approach to the prediction of fault-zone properties, and use this understanding to develop flow simulations of faulted and

fractured reservoirs, with and without stress-sensitivity, covering a range of scales. We will create geomechanical simulations of the basic fault-zone creation processes, enabling

predictions of deformation-induced changes to the petrophysical characteristics of the fault-rocks and damage-zone materials. We will simulate flow through and across fault

zones, and through fractured systems, specifically addressing cross-scaling issues when linking geomechanical and multi-phase fluid flow problems. The concepts to be

developed in this work will be used in case studies, from which we demonstrate how the new knowledge can be used effectively to understand and predict fluid flow in complex

reservoirs.

Title: Behaviour and Modelling of Fault / Fracture/Fluids Systems

Sponsors Confirmed: BG Group, BP, ConocoPhillips, DTI, Hess, Maersk, Shell, Statoil, Total

Project No. : 3068 PSD RFI ITF Funding (£k): 350 Duration (Months): 36

Summary: Open fractures have significant effects on reservoir production but are notoriously difficult to detect or predict. Individually the two dominant fracture identification methods,

seismic anisotropy & geomechanical modelling, can have significant uncertainties. The project combines the strengths of fracture detection via seismic anisotropy and fracture

prediction from geomechanical modelling to develop a Robust Fracture Identification (RFI) workflow, using an appropriate field identified with our sponsor group. RFI will assess

seismic anisotropy using pre-stack 3D offset-azimuth attributes and will develop the equivalent geomechanical interpretation. Using these fracture data sources & insight from

synthetic modelling, the combined geomechanics-seismic RFI workflow will be developed & applied. RFI provides the interface between seismic and geomechanics & can use

existing seismic anisotropy information.

Title: Robust Fracture Identification via Seismic Detection and Geomechanical Prediction




Project No. : 3081 PSD TransGen ITF Funding (£k): 118 Duration (Months): 24

Summary: Improved characterisation and incorporation of faults in flow models is a pre-requisite to optimising production strategies within structurally complex reservoirs. A geologically

palatable method for attaching fault transmissibility multipliers to reservoir flow simulation models has recently been jointly developed and implemented in commercial

software, referred to as TransGen, by the project partners. The proposed project will develop beyond our existing capabilities, which determine fault transmissibility multipliers

as a function of fault-rock thickness and single-phase permeability, to develop a suite of methods implemented in modular software for the incorporation of fault-zone

geometries and two-phase fault-rock properties in reservoir flow simulators. The methodologies will be complemented by research that examines the calibration of fault

property and geometry predictors to dynamic reservoir flow information.

Title: The implementation of methods for the inclusion of fault zone geometries and two-phase properties in reservoir production flow simulators

Sponsors Confirmed: Shell, Statoil

Project No. : 3082 PSD FIFT ITF Funding (£k): 240 Duration (Months): 24

Summary: Few constraints are available on the geometric and hydraulic properties of faults within turbidite sequences. Of particular interest is the impact of faults of different size on the

geometric and hydraulic connectivity of turbidite beds and sandbodies, and the inter-relationships of lithology/lithofacies with fault system architecture and fault zone

permeabilities. The classic turbidite succession of the Taranaki Basin, New Zealand is exposed along 25 km long cliffs and hosts two producing reservoirs for which seismic and

well data are available. Quantitative analysis and modelling of a population of normal faults within this area, combined with geological and flow modelling of a representative

suite of faulted turbidite reservoir architectures will provide a basis for addressing recurring issues related to fluid flow in faulted turbidite reservoirs, such as reservoir

compartmentalisation on production time scales and the distribution of unswept oil in older fields. This project will assist sponsors in alleviating production problems from

faulted turbidite reservoirs by providing them with appropriate quantitative fault data and statistics from a classic turbidite sequence and by identifying the risks associated with

production from different combinations of generically defined turbidite reservoir and fault architectures.

Title: Quantitative characteristics of faults and fault zones and their impact on flow within deep water turbidites, onshore New Zealand

Sponsors Confirmed: BG Group, BP, ConocoPhillips, Hess, Maersk, Shell, Statoil, Total

Project No. : 3090 PSD COFFERS ITF Funding (£k): 493 Duration (Months): 36

Summary: This proposal aims to develop a technique for using production data to constrain predictions of faults and fractures away from wells. The technique involves the statistical

correlations over time of production and injection rate fluctuations in wells, which, from previous work, appear to be generally influenced by changes in geomechanical strain

focussed on the faults and fractures in the reservoir. The method therefore has the potential to monitor the changing patterns of conductivity of the structural elements as the

reservoir is developed. The statistical technique will be applied to real field data, and the physical processes involved will be studied with a coupled geomechanical simulator,

which will also provide synthetic data for confirmatory statistical analysis.

Title: Calibration Of Faults and Fractures Extracted by Rate Statistics




Project No. : 3098 PSD ArKex ITF Funding (£k): 384 Duration (Months): 6

Summary: The proposal describes 6 months work to prepare a detailed build plan for an airborne superconducting gravity gradiometer system including sensor, cryogenics and airborne

system and to develop a data logger, data processing software, and interpretation software.

ARKeX is a company being established by Oxford Instruments and ARK Geophysics Ltd with the purpose of building and flying gravity gradiometers; capital is currently being

raised to fully establish the business and fund the building of 4 instruments. This project will enable critical system specification issues to be resolved, reducing the risks and

uncertainties in the business plan.

Title: Superconducting Gravity Gradiometry Build Plan

Sponsors Confirmed: Anadarko, DTI, Hess, Shell

Project No. : 3105 PSD MLP ITF Funding (£k): 197 Duration (Months): 24

Summary: Novel magnetic techniques are proposed to provide a rapid, cheap, non-destructive means of characterising high resolution permeability variations in low permeability

reservoirs. The techniques can be applied at a variety of scales (probe, plug, whole core) on consolidated and unconsolidated core. Rapid anisotropic magnetic measurements of

the intrinsic grain fabric will be used to predict the permeability anisotropy in low permeability reservoirs.

The magnetic measurements will also be used to accurately quantify wireline gamma ray cut-off values for distinguishing between clean and shaley sand, and for improved

estimates of net pay intervals. The magnetic techniques will further be utilized to provide improved interpretation and calibration of image log data in tight interbedded thin

sand and shale reservoirs.

The possibility of a potential downhole magnetic susceptibility tool for predicting permeability in low permeability reservoirs will be assessed.

Title: Magnetics as a rapid new tool for characterising high resolution permeability variations in low permeability reservoirs

Sponsors Confirmed: BG Group, BP, Chevron, DTI, Shell, Total

Project No. : 3110 PSD GASFLOWPERM ITF Funding (£k): 140 Duration (Months): 24

Summary: We plan to develop a hierarchy of analytical and simplified numerical models to describe the fluid dynamics of gas from a low permeability porous rock to a well. The work will

account for (primarily vertical) flow between relatively high and low permeability layers and the effects of fractures in such formations; we will also examine the importance of

well geometry (horizontal, vertical, fractured) and pressure drawdown in controlling the production history from a formation. The modelling will have specific targets, including

development of simple dimensional analysis and scaling laws to determine the dimension and shape of regions within the reservoir which may be depleted over a given

production time scale, for simplified well configurations and models of the permeability structure of the reservoir. The key new model results and associated new physical

understanding will be communicated to the industry through workshops and short courses coupled with new simple software tools; the new models should provide a powerful

complement to more conventional reservoir simulation.

Title: Gas Flow in heterogeneous low permeability rock

Sponsors Confirmed: BG Group, BP, Chevron, ConocoPhillips, DTI, Shell, Total



Project No. : 3111 PSD SWET ITF Funding (£k): 153 Duration (Months): 24

Summary: Based on our experience and understanding of flow mechanisms in the near wellbore region, two methods to alleviate the negative impact of condensate banking have been

identified. The first method relies on improving gas-condensate relative permeability using ultrasonic waves, which are generated by placing the source down hole. In the

second method the near wellbore rock wettability is altered to intermediate gas-wet by adsorption of polymer. The scope of both studies is limited to evaluation of key features

of the methods, which are essential to their success. Both studies are experimental with duration of one year each.

Title: Improving Gas Condensate Well Productivity in Tight Formations using Ultrasonic Waves and Altering Rock Surface Characteristics


Project No. : 3115 PSD PUP ITF Funding (£k): 130 Duration (Months): 12

Summary: This work aims to examine the effect of reservoir anisotropy and well placement on productivity from horizontal (and other) wells drilled underbalanced, and/or used in any

other circumstances which are likely to induce significant stress-sensitive permeability changes, e.g unconsolidated or low perm reservoirs. Traditional well test analysis cannot

resolve the effects of non-constant parameters on the pressure changes measured in the wellbore, such as the effect of unknown well length and unknown flow contribution by

different sections of the wellbore. The permeabilities and skin factors calculated are not representative of the formation. This is further compounded by the fact that the

permeability is inherently anisotropic: variations in vertical and horizontal permeability impose restrictions to the flow regimes developed around the wellbore and importantly

in the real world these are exacerbated by the variation in stress developed as a result of pressure drawdown. The work will use a geomechanics simulator coupled to a flow

simulator to model the responses of horizontal (and other) wells under a range of physical parameters. The pressure drops calculated will be used to identify the uncertainties

associated with traditional well test analyses. A set of generic functions for different reservoir models will be developed to attempt to modify the calculated permeabilities,

stress-sensitive and other skin factors, and productivities to represent real reservoir properties. The methodology and modelling capability developed will also be of use in

making a reservoir-specific prediction of the potential benefits of drilling underbalance.

Title: Understanding Productivity in Underbalanced-Drilled Wells




Project No. : 3125 PSD DAISI ITF Funding (£k): 90 Duration (Months): 9

Summary: This proposal is concerned with the development and use of novel signals for improved resolution, detection and classification of hydrocarbon bearing reservoirs.

The signals are based on various parametric forms of chirp (time-varying) signals. The proposers have developed a technique called Fourier Extension Analysis that allows signals

containing multiple chirp signals to be analysed in a manner similar to sinusoid analysis by Fourier Transform. Recent work has shown that multiple chirp signals occur frequently

in nature (bats, dolphins) and that these creatures have greater resolution capability by a factor of 1 x 105 than their apparent bandwidth suggests. Furthermore, sensitive

changes to the parameters of these chirp signals can be measured as they pass through dispersive media which enables different materials to be characterised. This is similar to

using signals in a Vernier fashion whereby greater resolution can be achieved by a combination of lesser resolution devices. Indeed it is now known that bats tend to identify by

shape and dolphins identify by material classification.

The project will be split into three phases as follows:

Phase 1: Create Benchmark of current resolution and materials imaging capability of existing Seismic.

Agree numerical model of overburden, reservoir and currently used seismic signals with the Industry Partners. Demonstrate the use of current signals and processing to arrive at

a resolution and materials imaging benchmark from which further methods and signals can be assessed. This is estimated to take 2 months and cost £22.2k.

Phase 2: Demonstrate improvement in resolution and materials imaging capability through use of new processing technology.

Based on the numerical model that has been agreed within Phase 1 Process the seismic signals that were also agreed in phase 1 using Fourier extension analysis techniques. It is

anticipated that this will demonstrate improved measures of dispersion and improved resolution of both layer thickness and material. This is estimated to take 3 months and

cost £33.3k.

Phase 3: Demonstrate improvement in resolution and materials imaging capability through use of new processing technology and new signal interrogation.

Based on the numerical model that has been agreed within Phase 1 interrogate the model using new signals and process them using Fourier extension analysis techniques. The

processing will be optimised to the signals resulting in a further improvement in resolution of both layer thickness and material. This is estimated to take 4 months and cost

£44.5k.

Title: Data Accuracy and Improved Seismic Imaging

Sponsors Confirmed: BG Group, BP, Chevron, Petro-Canada, Shell

Project No. : 3126 PSD SWOP ITF Funding (£k): 116 Duration (Months): 9

Summary: Active EM sounding has applications as a hydrocarbon indicator, and a reservoir mapping/monitoring tool. It has already been used with success in deepwater. However, its

operating envelope is currently limited by a phenomenon known as the 'airwave' which occurs in shallower water when the useful transmitted EM signal passing through the

subsurface, used to image the sub-surface, is swamped by a signal passing through the water column and free air.

OHM has screened, for feasibility, a number of development solutions to this problem. Through, this screening it was clear that two methods offer technically appropriate routes

to success. This proposal is for the implementation and testing of those methods, with the objective of bringing active EM sounding into the UKCS by the end of 2003.

Title: Project to develop and test 'Shallow Water' active EM sounding in the UKCS

Sponsors Confirmed: BG Group, BP, Chevron, Eni, Shell, Total



Project No. : 3128 PSD SINBAD ITF Funding (£k): 850 Duration (Months): 54

Summary: In this project we make a systematic effort to leverage recently developed techniques in modern Computational and Applied Harmonic Analysis to seismic imaging, inversion and

processing. Application of these new ideas involves a shift away from traditional operator design and towards the construction of very sparse, localized, directional and

multiscale basis-function decompositions for data and image. These basis functions are not only designed to optimally represent data and model (Earth), but they are also very

suitable for processing and migration. With the sparseness and locality of these basis functions, we are able to build the next generation of seismic processing and imaging tools

that (i) preserve the edges in data and image; (ii) drastically improve the signal to noise ratio; (iii) limit smoothing and imaging artifacts. By replacing conventional linear inversion

by non-linear estimation techniques that explore these optimal properties, we are able to gain substantial improvements in image quality and resolution. Similar improvements

have been achieved in medical imaging using comparable techniques.

Title: Seismic Imaging by Next-generation BAsis-function Decomposition

Sponsors Confirmed: BG Group, BP, Chevron, ExxonMobil, Shell

Project No. : 3130 PSD BLISS ITF Funding (£k): 299 Duration (Months): 37

Summary: Noise-reduction algorithms in seismic processing are often based on the statistical assumption that noise is Gaussian, white, and spatially not correlated. Unfortunately there is

often no physical reason why this should be the case. Instead we propose an analysis of the benefits of algorithms recently developed to solve the problem of blind separation of

signals – a rapidly emerging topic in the signal processing community. These techniques are based on the assumption that noise and signals display mutual statistical

independence which is arguably a physically more justified condition. Until now only a few isolated attempts have been made to employ these techniques in seismic data

processing. However, initial results look promising and significantly improved signal-to-noise ratios were obtained. We will investigate and implement these newly developed

techniques for advanced data processing and noise reduction to increase the resolution of conventional seismic data and thereby exploration prospects.

The project will be divided in three work packages between teams from Leeds and Grenoble. Leeds will start with a critical evaluation of existing signal-separation techniques.

Grenoble will lead theoretical development while keeping in mind the statistical characteristics of seismic data. Leeds will then use the acquired expertise to incorporate the

most suitable techniques into the noise-reduction toolbox and apply them on select datasets.

Title: Blind Identification of Seismic Signals

Sponsors Confirmed: BG Group, BP, Chevron, DTI, Shell



Project No. : 3153 PSD FULLWAVE ITF Funding (£k): 964 Duration (Months): 36

Summary: Conventional tomographic imaging uses travel times and ray-tracing to produce quantitative-but-low-resolution

velocity images of the subsurface. Conventional depth migration uses low-resolution velocity models to reposition

reflected energy in the sub-surface to produce a semi-quantitative reflectivity image with increased spatial

resolution. In contrast, full-wavefield tomographic techniques seek to determine a highly-resolved, quantitative

model of the sub-surface that is able to explain the entire seismic wavefield including those phases that

conventional processing and migration seek to remove. Such methods have the potential to image the subsurface

with significantly improved spatial resolution, to provide fully quantitative images of physical properties in the

subsurface, and to allow effective imaging using novel source and receiver geometries – especially high-resolution,

time-lapse, 3D imaging of the reservoir using surface shots into fixed arrays in horizontal wells.

Full-wavefield methods are now well-established in two-dimensions; however their application to genuine

exploration and production problems will be limited until they can be usefully extended to deal with threedimensional

structures and three-dimensional arrays of sources and receivers. Such an extension is

straightforward in principle, but presents a daunting computational challenge in practice. We seek to provide a

computationally tractable solution to this problem that will allow practical full-wavefield imaging of 3D surface and

sub-surface seismic data using existing and soon-to-be-available computer hardware.

Personnel & partners: list key personnel and any project partners, specifying their expertise and role in the project

Title: Full-wavefield 3D Seismic Tomography

Sponsors Confirmed: BG Group, Chevron, ConocoPhillips, DTI, Shell, Total

Project No. : 3164 PSD SMA ITF Funding (£k): 270 Duration (Months): 36

Summary: In many areas, contamination by multiply-reflected energy provides the major limitation to the resolution and signal-to-noise-ratio of surface seismic data. These limitations

provide the principal source of uncertainty and risk in petroleum exploration, and they provide an important source of risk in production and development. The central objective

of this proposal is to bring three newly developed concepts, for which there is already proof of principle, from a research environment into production. These three new

approaches together appear to provide a complete solution to the surface-related multiple problem, and have the potential to do so for inter-bed multiples. There is at present

no generally-effective, commercially-available solution to either of these two problems.

Multiple attenuation is a long-standing problem in the reflection seismic industry; there are two related aspects: multiple prediction and multiple subtraction. The project targets

both aspects by developing a fully data-driven algorithm for multiple prediction, and a robust technique for multiple subtraction. The former involves multiple prediction without

explicit knowledge of surface and sub-surface structure, or of the source signature. The latter involves attenuating multiples without removing or altering primaries. The

completion of the project will make available a major breakthrough in seismic multiple attenuation on a commercial basis.

Title: Seismic Multiple Attenuation

Sponsors Confirmed: Aramco Services, Chevron, SINOPEC



Project No. : 3182 PSD COMPFRACT ITF Funding (£k): 182 Duration (Months): 36

Summary: The evolution of the material and stress state within, or near, a reservoir often results in the development of localized deformation zones or shear bands, manifested as fractures

at the wellbore scale or faults at the reservoir scale. These discontinuities have a pivotal role in the physically observed behaviour and the reservoir management strategy.

While prediction of initiation and subsequent evolution fracture/faults is essential for accurate geomechanical modelling, rigorous formulations that address this issue are not

available in commercial codes. This fundamental limitation will be address in this project. A rigorous computational mechanics formulation, which importantly also includes the

experimentally observed physics of the response in the fault/fracture zone will be developed and implemented within commercially supported software. This will provide a

practical physically realistic model for prediction of the initiation and evolution of fractures/faults at both the wellbore and reservoir scales. The proposed research has a large

potential impact on several reservoir engineering applications.

Title: A Computational Framework for Prediction of the Initiation and Evolution of Fractures and Faults

Sponsors Confirmed: BP, Chevron, Eni, ExxonMobil, Shell, Statoil, Total

Project No. : 3189 PSD IPEGG ITF Funding (£k): 590 Duration (Months): 36

Summary: Prediction of wellbore stability, reservoir compaction, fault stability during production and whether or not to conduct 4D seismic surveys requires more thorough integration of

petroleum engineering, geomechanics and geophysics. Here we propose to conduct such a multidisciplinary study in which coupled fluid flow – geomechanical models are used

to predict reservoir behaviour (i.e. stress changes, compaction, fault reactivation) during production. We also propose to use these models to assess the usefulness of applying

sophisticated passive (microseismic data) and active source (e.g. AVOA) geophysical techniques to monitor stress changes in the reservoir. A key part of the integrated study will

be to assess how geophysical indicators of stress distributions within reservoirs can be integrated with coupled-stress fluid flow models to predict reservoir behaviour. The study

brings together brings together world leading research groups in reservoir deformation, applied geophysics and finite element analysis applied to geo- and civil engineering.

Title: Integrated Petroleum Engineering - Geomechanics – Geophysics – Next Generation Technology for the Petroleum Industry

Sponsors Confirmed: BG Group, BP, Eni, Statoil

Project No. : 3218 PSD FR3DA ITF Funding (£k): 120 Duration (Months): 24

Summary: Fluid flow through fractured reservoirs is critically dependent on the three-dimensional (3-D) architecture of sub-seismic fault and fracture networks. 1- and 2-D fracture

attributes are determined routinely from core and outcrop analyses, but constraining equivalent 3-D fracture attributes from these data is non-trivial. We propose to address this

problem by applying innovative digital data acquisition, visualisation and analysis workflows to construct deterministic 3-D fracture models derived from outcrops, quarries and

mines in a range of tectonic and sedimentological environments. These models can be used in numerical flow simulations to investigate the sensitivity of fluid flow to natural

variations in the sub-seismic structural architecture, and to address the issue of how best to upscale these data for input into reservoir-scale flow models.

Title: Fractured Reservoir 3-D Digital Atlas

Sponsors Confirmed: BG Group, DTI, Shell



Project No. : 3219 PSD FIFT2 ITF Funding (£k): 300 Duration (Months): 24

Summary: Recent results of the FIFT research project have highlighted a variety of shortcomings associated with existing methods for modeling faulted deep-water turbidites. Conventional

modeling methods, using, for example, stochastic shales or sands, fail to incorporate fundamental measures of sequence architecture and connectivity and therefore often

provide models that, in important respects, differ from the architectures observed in high quality turbidite reservoir analogues. For example, conventional models of well layered

and thin-bedded turbidite sequences can be characterized by more permissive and homogeneous model architectures, within both bed-scale and upscaled models, than are

justified by observational constraints. These shortcomings are compounded in faulted reservoirs where faults, including those which are sub-seismic, can have a more profound

impact on bed-scale connectivities, than is reflected in poorly upscaled models. Significant uncertainties associated with fault flow properties only serve to exacerbate potential

errors associated with model generation and further diminish the value attached to both history matching and production forecasting studies. During the course of the FIFT

project, a novel approach to faulted turbidite modeling has been developed which provides a means of bed-scale modelling of the flow response of faulted turbidites and

provides a basis for generating properly upscaled properties for inclusion in full-field reservoir production models. In response to existing FIFT sponsors, this follow-on proposal

will develop and implement a comprehensive modeling approach for faulted turbidite reservoirs, including bed-scale sedimentology and fault modeling, combined with

appropriate upscaling methodologies. This modeling suite will be tested on assets provided by sponsors and will be delivered as an integrated set of software tools.

Title: Quantitative Characteristics of Faults and Fault Zones and their Impact on Flow within Deep Water Turbidites, Onshore New Zealand

Sponsors Confirmed: BG Group, BP, ConocoPhillips, Shell, Statoil, Total

Project No. : 3222 PSD ISF2 ITF Funding (£k): 450 Duration (Months): 36

Summary: A major part of this research project will be to apply the principles of structural

geology to client reservoir data. Study of realistic fracture development and

characteristics will provide the best means to incorporate abutting relationships and

different properties associated with shear and extension fractures. With these further

characteristics included, methods of importing deterministic fractures or stochastically

populated discrete fracture networks (DFN) into reservoir models will be substantially

improved upon.

Title: Improved Simulation of Fractured & Faulted Reservoirs

Sponsors Confirmed: BP, ConocoPhillips, ExxonMobil, Scottish Enterprise, Total




Summary: This scoping study was initiated by ITF in order to assist with identifying portfolio of high potential technologies to maximise hydrocarbon recovery from mature fields and new

developments in three core areas:-

1. Tertiary Oil Recovery

2. Tight and Residual Gas Recovery

3. Reservoir Monitoring and Surveillance

The objective of the scoping study was to deliver a series of options and roadmaps to guide investments and development activity in future years. This will result in the

development of several potential investment streams within specific ITF projects that will help to drive key technologies from concept towards deployment and commercial

realisation.

Title: Maximising Recovery fromHydrocarbon Reservoirs - Scoping Study

Sponsors Confirmed: BG Group, BP, Chevron, CNR, ConocoPhillips, DTI, Eni, Shell, Total

Project No. : 3226 PSD GASCALC ITF Funding (£k): 190 Duration (Months): 24

Summary: We propose to develop simplified semi-analytic models for gas flow in heterogeneous low permeability rock, to account for (i) damage near the well-bore; (ii) fractures

pervasively distributed through the formation; (iii) faults providing dominant conduits for flow; (iv) finite lenses of high permeability embedded in the low permeability

formation; and (v) anisotropic reservoirs with different horizontal and vertical permeability. Also, the models will be developed to interpret how inflow profiles may evolve over

the life of a reservoir, and this will be compared with field data.

The models will be verified by full numerical calculations of the flow patterns, and we will then adopt the models for use in a spreadsheet tool to enable rapid scoping

calculations of the gas flow: for use in both estimation of reserves, production rates with time and also for estimating the time for depletion of the reservoir. This spreadsheet

will follow from the existing GASCALC spreadsheet tool and will provide substantially more functionality to enable modelling of a broader class of reservoir types.

Seminar/Workshops will be offered for the different companies to share the results of the research, and to explain the use of the GASCALC tool.

Title: Gas Flow in heterogeneous low permeability rocks

Sponsors Confirmed: BG Group, BP, Chevron, ConocoPhillips, Eni, Shell



Project No. : 3227 PSD JIBA ITF Funding (£k): 530 Duration (Months): 36

Summary: The project extends prior work on the development of joint inversion of diverse geophysical datasets. The use of alternative geophysical methods such as electromagnetics and

gravity has gained in importance for applications where seismic data does not provide unambiguous images, such as the sub-salt and sub-basalt problem. Electromagnetic data

are particularly useful, because the salt or basalt layers are transparent to the electromagnetic waves. Gravity data also contain valuable additional information because the

density contrast of the salt or basalt is high and has a pronounced impact on the gravity signal. The combination of these non-seismic data with seismic data in a formal joint

inversion framework capitalises on the complementary information content in the different data sets and subsequently will lead to an improved, less ambiguous image of the

entire sub-basalt and sub-salt region. An important aspect of the project is to underpin the joint inversion result with a Bayesian based analysis to quantify uncertainty in the final

model and provide a framework for more efficient approaches for high-dimensional problems.

Title: Joint Inversion of Seismic, Gravity and MT Data

Sponsors Confirmed: Chevron, ExxonMobil, Nexen, RWE, Shell, Statoil, Wintershall


Summary: We propose a feasibility study of the potential mechanisms for microbially enhanced oil recovery (MEOR) to give increased production of crude oil from North Sea oilfields. The

study would examine the scientific basis of each mechanism for MEOR, excluding single-well treatments, and evaluate the potential benefits using material balances from a

simple reservoir model. The project team of Gray, Foght, Yarranton, and Yeung provides skills in microbiology, biochemical engineering, interfacial science and reservoir

engineering. The cost of the study and report will be $62,413 (Canadian $), or £29,868 (GBP). Additional costs would be incurred if ITF wishes to have team members participate

in a meeting with the sponsor companies, or if the project is executed under a Technical Service Agreement between ITF and the University of Alberta.

Title: Conceptual Study on Microbially Enhanced Oil Recovery: Potential Mechanisms for Successful Applications

Sponsors Confirmed: BP, Chevron, ConocoPhillips, Eni, Maersk, Shell, Statoil, Total



Project No. : 3229 PSD MLP2 ITF Funding (£k): 320 Duration (Months): 24

Summary: Phase I demonstrated how magnetic techniques can rapidly and non-destructively provide improved estimates of key petrophysical parameters (such as clay content,

permeability etc) in low permeability reservoirs, and help to solve specific problems in several company case studies. The research won two 2nd best paper awards: at the SCA

(Society of Core Analysts) International Symposia in Toronto (2005; out of 118 submissions) and Trondheim (2006; out of 86 submissions). In Phase II we are developing even

better techniques (using a range of magnetic field values) that enable improved estimates of permeability controlling clays. Part of the work will improve the clay typing

database, and the influence of different clay types on permeability. The techniques also allow the secondary influence of other minerals (especially iron oxides) on permeability

to be quantified. Another key aspect will be to use magnetics to quantify the effect of core cleaning (we have shown that hot soxhlet cleaning can remove clay in some samples).

Improved anisotropic measurements will also form an important part of Phase II. Phase I suggested the potential of using magnetics to incorporate diagenetic effects in reservoir

models, and this will be further investigated in Phase II. Phase I made significant advances in the characterisation of thin-bedded turbidites. In particular, in identifying thin beds

and showing that sand and shale samples from the same turbidite type gave identical normalised hysteresis curves. This was an extremely important

Title: Magnetic characterisation of petrophysical parameters in low permeability reservoirs (Phase II)

Sponsors Confirmed: BP, Chevron, Scottish Enterprise, Shell, Total

Project No. : 3236 PSD WISE (Well Integration

with Seismic and

Electromagnetics)

ITF Funding (£k): 1025 Duration (Months): 36

Summary: Improved reservoir management and production optimisation demands require accurate characterisation of reservoir properties and their changes through time. By integrating

complementary sources of information and exploiting the strengths of each, estimates of rock and fluid properties such as gas saturation and porosity can be obtained with

greater confidence than from any one data type alone.

This project will investigate the integration of three contrasting and complimentary data types: seismic, controlled source electromagnetic and well log data, and will examine

how they can most effectively be used in determining reservoir and fluid properties to reduce ambiguity and risk. The goal of the project is to develop methods which allow rock

and fluid properties to be predicted from the integration of surface seismic, CSEM and well log data. The ultimate aim is to provide maps of reservoir properties (such as

porosity or hydrocarbon saturation) across the extent of a field. The approaches developed will help industry exploit the strengths of these diverse data types, and thus add

value to both existing data and new acquisition.

Title: Wells Integrated with Seismic and Electromagnetics

Sponsors Confirmed: BERR, Chevron, Dong Energy, Maersk, NOIL Energy, Total



Project No. : 3241 PSD Full Wave III ITF Funding (£k): 1280 Duration (Months): 36

Summary: P-wave seismic reflection data provide high spatial resolution of the sub-surface, and delimit structure accurately, but struggle to identify pore fluids and provide minimal

constraints upon permeability. In contrast, controlled-source electromagnetic techniques (CSEM) measure a property that relates strongly to hydrocarbon content and to the

interconnectivity of pore space. However the structural resolution of EM data is limited, especially in complex geometries. Full elastic seismic data are also sensitive to

hydrocarbon content in the subsurface.

This project is concerned with the joint inversion and interpretation of 3D seismic and 3D CSEM data in order to combine the structural fidelity and depth control of P-wave

reflection imaging with the direct hydrocarbon sensitivity of both CSEM and full elastic seismic data. We are further concerned to do this within a scheme which has a minimal

requirement for subjectively allocating resistivity structure to particular features previously identified within the seismic images, and we are concerned to quantify uncertainties

and non-uniqueness in the final result.

The project builds upon experience gained under a previous ITF project – FULLWAVE I – in which we developed a method for 3D full-wavefield acoustic tomography which is able

to produce highly resolved P-wave velocity models in 3D from realistically sized field datasets; the full-wavefield approach lies at the heart of our proposed joint seismic-EM

inversion.

Title: Joint 3D inversion of full-wavefield P, S and CSEM data

Sponsors Confirmed: BERR, BG Group, BP, Chevron, ConocoPhillips, Eni, Maersk, Nexen, Rio Tinto

Project No. : 3258 PSD 3DTIGHT ITF Funding (£k): 228 Duration (Months): 24

Summary: This project focuses on combining outcrop data with hydraulic fracture modelling to improve the understanding of three-dimensional hydraulic fracture growth in fluvial tight gas

systems. The main outcome of this project will be to determine how different tight gas fluvial depositional environment systems, such as crevasse splays, channels, and point

bars, etc, affect hydraulic fracture growth in three-dimensions. Such an understanding will lead to improvements in hydraulic fracture treatment designs and, subsequently,

improved reserve recoveries. Onshore developments will benefit from this knowledge due to a better understanding of the necessary well-spacing to recover associated

reserves. However, offshore developments will profit at an even greater level since down-spacing in such environments can be cost-prohibitive and any improvement in the

understanding of three-dimensional drainage patterns will aid overall reservoir management.

Title: 3D Hydraulic Fracture Modelling of Tight Gas Fluvial Reservoir Systems

Sponsors Confirmed: ConocoPhillips, Eni, Shell, Total, Wintershall




Summary: Currently seismic analysis tools offer two types of surface picker. One is a simple 'bleeding' type algorithm, and the second uses a correlation function along the normal of the

plane. Both techniques produce ‘patchy’ broken surfaces that required a large manual effort to complete.

The technique proposed by Soundmotion will explore the full three-dimensional space using suitable global transforms to generate feature sets for KIA to classify and fit. This

approach will deliver a more robust picker capable of dealing with vertical discontinuities (faults) and areas of missing data. The search for a suitable transform will concentrate

on the domain of image feature extraction.

Title: Seismic Signal Processing and Data Analysis

Sponsors Confirmed: Chevron, ConocoPhillips, Scottish Enterprise

Project No. : 4035 PPD SPINAV2 ITF Funding (£k): 300 Duration (Months): 12

Summary: SPINAV Phase I concluded in September 2004. It demonstrated the hover capable RAUVER Autonomous Underwater Vehicle (AUV) carrying out pilotless inspection of a riser-like

structure in test tank conditions. It used the DIDSON sonar for station keeping/tracking, SLDI Fluorotrak fluorosene sensor for leak detection, and SeeByte SeeTools and SeeTrack

for sensor processing, vehicle control, mission planning and post mission analysis.

Building on this success, phase II will substantially extend the scope and at sea readiness of the system by:

1.Extending the range of AUV inspec@ons to include objects such as anchor chains, jackets/ship hulls

2.Improving the speed of AUV inspec@on through development of improved vehicle dynamic control system

3.Reviewing use of Fluroscein leak detec@on to assess other new sensing systems that directly detect oil

4.Improved visualisa@ons & 100% coverage check through mosaicing & texture mapping onto CAD models

5.At sea demonstra@ons in sea lochs with appropriate structures

A £60k ticket price is sought

Title: Subsea Pilotless Inspection with an Autonomous Vehicle (Phase II)

Sponsors Confirmed: BP, Scottish Enterprise



Project No. : 4042 PPD ITF Funding (£k): 300 Duration (Months): 24

Summary: The main objectives of this two-year research proposal are: 1) Developing methods for determining the hydrate safety margin of pipeline fluids, 2) Developing techniques for

detecting initial hydrate formation in pipelines. The first is to ensure that the system is adequately inhibited against hydrate formation and optimising inhibitor injection.

Whereas the second is to develop a warning system if hydrates start to form (prior to hydrate build up and pipeline blockage). The ultimate objective is to develop online

monitoring and warning systems, but at this phase of the project the methodology will be based on downstream fluid sampling. The successful implementation of the first part of

this project would result in optimising inhibitor injection rate as a function of the system parameters (i.e., changes in the water cut, etc.), as well as minimising the risk associated

with human error in adjusting pump rates and other operational parameters. The second part of the project will ensure early warning mechanisms are in place to prevent

massive hydrate formation and pipeline blockage. Furthermore, the project will identify the most promising techniques for future development, in particular online/live

monitoring and detection.

Title: Flow Assurance: Hydrate Monitoring and Warning System

Sponsors Confirmed: BP, Chevron, Petronas, Statoil, Total


Summary: This proposal covers the development of the Caledyne Improved Seal. The plan is to carry out development tests on the Caledyne packer seal variant to establish the optimum

design. Further tests will be carried out to qualify the final design to ISO 14310 standard.

Following successful completion of the proof of concept phase, a partner would be sought from the operator community to provide an opportunity to test a tool in a field

application.

Title: Improved Downhole Seal (Metal-to-Metal, non elastomeric)

Sponsors Confirmed: BP, Chevron, Shell



Project No. : 4090 PPD Torus™ ITF Funding (£k): 320 Duration (Months): 9

Summary: The Caledyne Torus™ Safety Valve is designed for applications where a conduit is required through the centre of a down hole safety valve while maintaining full safety sealing

capabilities. A replaceable insert is located in the centre of the valve, which allows for a rotating, reciprocating or a stationary conduit. The valve is hydraulically actuated via a

control line to open the valve and allow flow through the tool. The insert section can be easily removed to allow for intervention work to be carried out through the valve.

The valve can be designed either as tubing mounted or retrofittable in an existing safety valve profile utilising the hydraulic line in place to operate, making it ideal in applications

where a full work over is not possible due to rig availability or financial constraints. The most common conduits through the valve could include sucker rods for PCP or Rod Pump

applications, electric cables for ESP pumps, macaroni string for gas lift and Fibre Optic.

The proposal is to complete the design for an insert type Torus™ safety valve for a specific TRSCSSV, build a prototype and test in a laboratory and also at an onshore facility,

such as DTL, Aberdeen. It is intended that the tool would then be tested in accordance with API 14A at a suitable facility.

Title: Torus Insert Safety Valve

Sponsors Confirmed: BP, Chevron, ConocoPhillips, Total



Project No. : 4109 PPD LDHI ITF Funding (£k): 420 Duration (Months): 36

Summary: Flow Assurance is one of the major technical challenges in offshore development. Hydrates, wax,

halite and asphaltene deposition can all cause serious operational and economical concerns. The

industry needs innovative techniques to reduce the costs associated with flow assurance, improving

the overall recovery factor from marginal and mature oil/gas fields.

In recent years, the industry has made significant investment in a new family of hydrate inhibitors,

namely Low Dosage Hydrate Inhibitors or LDHIs. However, almost all existing LDHI

formulations have been developed by trial and error methods, and are generally system specific. In

addition, there are currently significant performance limitations with respect to the degree of

subcooling (within the hydrate region) and/or system pressure.

In the current previous phase of the project we have investigated the mechanisms of gas hydrate

formation and LDHI inhibition characteristics for various fluid systems. We also have developed a

number of novel techniques for evaluating the performance of basic polymers and their synergic

chemicals in delaying gas hydrate formation.

It is proposed to continue work by investigating a number of topics with respect to improving the

performance of Low Dosage Hydrate Inhibitors, and to assess means for reducing potential

environmental impacts. The proposed research programme will address various issues, including:

1. Effect of Condensate, Methanol, and Salt on the Performance of KHIs

2. KHI Compatibility with other Additives/Inhibitors (e.g., Corrosion, Scale inhibitors)

3. AA Evaluation for High Water Cut Systems and Sub Zero Conditions

4. Performance of KHIs under Low Degree of Subcooling and High Induction Time

5. Developing Testing Techniques for KHI and AA Evaluation

6. Designing KHIs for Structure-I Hydrates

7. Development of Environmentally Friendly ‘Green Inhibitors’

The following deliverables would be expected from the proposed research programme:

• Guidelines on how to minimise the adverse effects of condensate, methanol, and salt on the

performance of KHIs

• Guidelines on how to improve the compatibility of KHIs with corrosion and scale inhibitors.

• Evaluating the performance AAs at high water-cut conditions

• Information on the performance of AAs under ice forming conditions and the interaction

between alcohols and AAs

• Information on the suitability of KHIs in shut-in conditions

• Developing methodology for effective evaluation of LDHIs

• Improving current testing equipment and procedures, and try to standardise test methods

• Possible transportability of test result on one system to another system

• Potential KHI formulation(s) for sI hydrates

- 3 -

• Evaluation of at least three existing formulations and guidelines for future development

The research programme will be finalised based on the interest received from sponsors and the

Title: Low Dosage Hydrate Inhibitors

Sponsors Confirmed: Champion Technologies, Clariant Oil Services, Petrobras, Total, Wintershall



number of sponsors.

Project No. : 4300 PPD HIPPS ITF Funding (£k): 275 Duration (Months): 12

Summary: Hydraulic Subsea HIPPS Control

• A simple and cost effective subsea pipeline protection (HIPPS) solution .

• A SIL 3 HIPPS solution available within reduced delivery times.

• An all-hydraulic HIPPS control, using no programmable electronics.

This design uses a reference pressure from the subsea controls system hydraulic supply to set a HIPPS ‘trip’

pressure. No instrumentation or programmable electronics are used in the ESD decision making process.

• Available as a package.

Using a modular approach to the system design, it will be possible to supply a HIPPS package, for installation onto

a manifold or stand alone structure within very limited timescales. No special features within the control system are

required to host the HIPPS package.

• This technology will be of interest to Project/Subsea Engineers with responsibility for control system configuration.

• The system can be tested and calibrated from a remote location (the surface) via a direct hydraulic link trough the

control system supply. During both normal operation and testing, this arrangement improves the reliability of the

system due to there being no reliance upon data from inaccurate or faulty subsea instrumentation.

• It can be used as a stand alone HIPPS or in parallel with a programmable electronic system in a layered

configuration. This can be a quick-fix rout to achieving the necessary SIL rating and keeping a project on track

Title: Subsea Hydraulic HIPPS Development

Sponsors Confirmed: CNR, Eni, Shell, Total



Project No. : 4305 PPD AcoustekTM ITF Funding (£k): 50 Duration (Months): 12

Summary: AcoustekTM - Remote Pipeline Inspection for Real-time Field Management

An acoustic technique for the detection of leakage and blockage in pipelines

- Access via existing flanges and fittings

- High accuracy over long distances

- Continuous monitoring capability to enable predictive monitoring

- Early fault diagnosis to enable corrective actions

Significant costs are associated with hydrate blockages and waxy deposits in pipelines

-This results in $2,000,000+/ day in lost production

Early detection could prevent this from happening

- AcoustekTM has been shown to routinely detect blockages less than 10% of the pipeline area

Using Acoustek could save considerable costs for Pipeline Operators and their Maintenance staff

Title: AcoustekTM - Remote Pipeline Inspection




Project No. : 4310 PPX LUX Monitor™ ITF Funding (£k): 20 Duration (Months): 4

Summary: LUX Monitor™ - A novel method for oil-in-water monitoring

Funding application for feasibility study

•Development of a novel, highly efficient oil in water detec@on measurement technology

•Advantage: Improved oil in water monitoring, without complicated extrac@ons using hazardous chemicals

•Novel method to monitor oil in water, with poten@al for maturing to online monitoring

Initial due diligence indicates no existing technology is based on the same principles

LUX Monitor™ provides an immediate response to analysis of produced water samples, is directly detectable without complicated equipment, and indicates quantity of oil

present to a high degree of accuracy

•Procedure does not require chemical extrac@on, it will simplify use and minimise the requirement for hazardous chemicals

The level of output using LUX Monitor™ has potential to be independent of the quantity of oil being highly measurable (to ppb). Presence of particulate matter should not

interfere with results

Title: A Novel Technology for Oil-in-Water Testing

Sponsors Confirmed: ConocoPhillips, ITF




Summary: Production enhancement through increased production using wasted energy

Caltec’s Wellcom boosting technology can be used both topside and sub-surface as an extremely cost effective means of boosting production and increasing revenue from

additional oil and or gas returns.

Our production boosting/enhancing technology is an extremely cost effective solution to allow for additional production returns from LP wells using available or wasted energy

on the platform/FPSO. The capital cost is far outweighed by the commercial returns available to the client/end user.

Enhanced Production – Caltec specialises in increasing production from existing wells by making better use of the available energy on the platform, maintaining and optimising

well production and increasing revenue by maximising production. This is possible by utilising our patented and fully proven Wellcom boost production enhancing system which

utilises a combination of jet pump technology and inline compact separation units to enhance production for multi-phase applications.

Technology that starts to pay for itself from the first day of installation to the last

Production or process engineers/managers as well as reservoir and drilling engineers

Title: Energy recovery - boosting production/enhancing field life using existing energy


Project No. : 4318 PPD HOPIT ITF Funding (£k): 25 Duration (Months): 3

Summary: Proposal to develop a software tool which will give Offshore Operators and Onshore Support Teams a ready means of both ensuring efficient operation of their hydrocyclones

and to monitor performance trends, so that long term low levels of oil in water discharged to sea can be maintained.

Likely to benefit from the software tool would include Asset Managers, Process Engineers, Offshore Installation Managers/Team Leaders and Control Room Operators"

Title: Hydrocyclone Operations & Performance Improvement Tool

Sponsors Confirmed: Chevron, CNR



Project No. : 4320 PPT MIMS ITF Funding (£k): 210 Duration (Months): 20

Summary: Production enhancement through improved MIMS water monitoring system

The objective of this proposal is to build and field test a novel diagnostic sensor to analyse water samples obtained from hydrocarbon reservoirs in oil and gas fields in the UK

and//or elsewhere.

- This technology has a number of application points both upstream and downstream of e.g. separators, injection pumps and/or dehydrators

- The technology uses miniature mass spectrometry to allow monitoring of oil in water to an extremely high sensitivity. It allow trace levels of oil in water to be detected and

quantified thus maximising oil production/recovery and minimise loss /contamination

- As a mass spectrometric technique, the technique is information rich (mass and concentration) and has a sub ppm sensitivity which is orders of magnitude greater than

competing technologies. The technology is novel and untried in the oil industry and potentially of great benefit to the oil industry worldwide

- The technology will allow maximised hydrocarbon recovery from UK reservoirs and is relevant to production analyst.

Title: Production Enhancement through improved MIMS Water Monitoring System

Sponsors Confirmed: BG Group, BP, Chevron, ConocoPhillips, Eni



Project No. : 4321 PPD AMPL ITF Funding (£k): 296 Duration (Months): 9

Summary: Regular pigging of most pipelines is essential to remove debris, ensure that flow in the pipeline is maintained at full capacity and to help minimise corrosion. However loading &

unloading of pigs is an unpleasant task, it is labour intensive and time consuming, opening the closure door on the launcher or receiver presents health, safety and environmental

hazards and consequently the task is not only costly but unpopular.

The vast majority of pig launchers require pigs to be loaded individually for each pigging run. Although a few automatic launchers exist, they generally utilise a complex

arrangement of multiple kicker lines/valves or release fingers/flaps for multiple launching. The latter mechanisms can not be retrofitted to existing traps, often require an

external power supply and, due to the complexity of their design, add substantially to the cost of a new launcher

PE has come up with the concept of automatically launching a number of pigs from an existing pig launcher (patent applied for) where no modification is required to the

launcher and no external power supply or human intervention is required as the pig launching is controlled by mechanisms built into the Pigs rather than the launcher itself.

A specially designed cassette is preloaded into the launcher and remains within the launch barrel. A number of special interlocking pigs are loaded into the in-situ cassette as and

when required. The number is dictated by the length of the trap. The interlocking mechanism allows each pig to be launched on its own as the status of the kicker line changes.

Petronas have joined the project with their contribution funding additional Subsea Study work.

Title: Development of Automated Multiple Pig Launching (AMPL) System

Sponsors Confirmed: BP, Chevron, Shell, Total


Summary: Bubbletherm development is in Phase 2, which involves production trials, full scale structural testing and laboratory material testing ( including Service Simulation ) The

Bubbletherm pipe joints resulting from the production trials are to be used for the structural testing. The aim of the current phase is to qualiify the system for projects.

Title: High Performance Non Pipe-in-Pipe Thermal Insulation System - Bubbletherm Phase 2

Sponsors Confirmed: BG Group, BP, Shell, Total



Project No. : 4334 PPT SWIT ITF Funding (£k): 770 Duration (Months): 19

Summary: SWIT provides an alternative to topsides seawater treatment by doing everything on the seabed. The system offers a subsea seawater treatment solution to add to existing

subsea pumping and christmas tree technology.

The SWIT system contains significant levels of innovation in 4 main areas:

• Solids removal – removal of inorganic solids levels down to 10μ

• Seawater sterilisation – via electrochlorination and AOP (hydroxyl radicals) to ensure sterile seawater is delivered all the way to the reservoir

• Shock dosing of biocide in a unique manner, to prevent the build up of biofilm

• All-electric operation – using a single electrical cable (no umbilical), allowing flexibility in water flood design and power supply source

These innovative techniques provide a very robust system and have recently been awarded patents and an ONS innovation finalist award in 2006. The key benefits of SWIT are:

• Greater flexibility in water flood design

• Easy add on capability at any stage of a field life

• Increased oil recovery via more effective field drainage

• All topsides well slots can be used for production instead of water injection

• Significantly reduced cost

• Reduced weight and space topsides

• Reduced environmental impacts

• Does not require long HP pipelines or deviated wells

The basic SWIT techniques enable a great deal of design flexibility and opens up a wide range of potential applications. SWIT promises to be a preferable alternative to existing

topsides seawater injection methods.

Title: Subsea Water Injection and Treatment

Sponsors Confirmed: ConocoPhillips, Gaz de France, Shell, Total



Project No. : 4335 PPX MEMCAP ITF Funding (£k): 20 Duration (Months): 4

Summary: The Robert Gordon University has developed a novel highly efficient gas separation module. The module has been developed specifically for the separation of carbon dioxide

from a range of streams including for example, natural gas or power station emissions exhaust gas streams.

The patented technology is based on simple porous ceramic materials which separate CO2 from the other gases by selective surface flow permeation. The driving force in this

process is adhesion followed by surface transport making the separation process dependent on surface area available.

A 3 year proof of concept study has already demonstrated high permeation rates and separation factors in laboratory conditions. As well as CO2 separation from natural gas,

there are technical indications that it can also separate H2S

Title: Non Chemical Modular Gas Treatment Technology

Sponsors Confirmed: ConocoPhillips, ITF

Project No. : 4354 PPD DR-Riser ITF Funding (£k): 248 Duration (Months): 24

Summary: The project will develop the world’s first sub-sea digital radiographic Non Destructive Testing (NDT) method for the reliable, volumetric inspection of flexible risers and riser

connectors to detect defects in the areas of most concern. Sub-sea radiography has been recognised (UKOOA Study Report on ‘State-of-the-Art, Flexible Riser Integrity’) as the

only inspection method that can potentially provide the type of information required to detect the defects of concern to major oil companies operating FPSOs. Remote

Operating Vehicle (ROV) manipulator tooling will be specified to deploy the sub-sea radiographic inspection system (see Section F, Figure F.1 for the project concept diagram).

Owing to the complexity of construction of marine flexible risers, there are concerns among the operators about the prediction of their service life and there have been several

in-service failures to date (see Section F of this proposal). Flexible risers are less frequently inspected (only by remote visual) than steel tubular risers and they do not lend

themselves to conventional NDT & inspection methods. There is no current method of volumetrically examining, in situ, the underwater flexible risers to ensure their continued

reliable high integrity of operation. The failure of a single riser could lead to the failure of adjacent risers, dramatic long term environmental damage, loss of oil production &

huge economic consequences for the operator. Potential global industry savings are £300M pa.

Title: Real time condition monitoring of down-hole casings for identification and location of corrosion and water breakthrough

Sponsors Confirmed: BP, Total



Project No. : 4357 PPD Hydraflow ITF Funding (£k): 200 Duration (Months): 24

Summary: This is a follow-up to an ongoing research programme due to completion in February 2008. The ongoing research started in September 2005 with support from the Scottish

Enterprise (SE) Proof of Concept Programme. The objective is to avoid gas hydrate and flow assurance problems in subsea pipelines by minimising/eliminating the gas phase by

encouraging gas hydrate formation (i.e., by adding water if necessary) but preventing their agglomeration and transporting the hydrates as slurry. In the receiving facilities the

hydrates and hydrocarbons are separated, while some of the liquid phase could be recycled to minimise inhibitor consumption, hence the “loop concept”. One or several wells

could be connected to the loop. It is believed that the concept will have many advantages, including, reducing/eliminating slugging and wax problems, reducing various inhibitor

costs and their discharge to the environment, reducing pipeline CAPEX and OPEX. It is believed the concept is applicable to various reservoirs, in particular water flooded and/or

matures reservoirs where the water-cut is already high.

In the first phase of the project, an extensive experimental programme has been conducted, simulating various production scenarios and fluid systems. The results are very

promising and show that the concept is feasible. However, all the tests conducted so far were in small scale set-ups. The market research, conducted as part of the SE funding,

reported a USD 1 billion per year opportunity for this innovation. However, the market research pointed out the need for large scale demonstration. The main objective of this

proposal is to upscale the previous tests in a large scale flow loop (funded by the Scottish Funding Council) and conduct further experimental work.

Title: A Multiphase Cold Flow Assurance Solution

Sponsors Confirmed: BERR, Petrobras, Scottish Enterprise, Total

Project No. : 4369 PPD HMEWS ITF Funding (£k): 395 Duration (Months): 24

Summary: The two main objectives of this two-year research proposal are: (1) developing methods for determining the hydrate safety margin of pipeline fluids, and (2) developing

techniques for detecting initial hydrate formation in pipelines. The first is to ensure that the system is adequately inhibited and optimising inhibitor injection, whereas the

second is to develop an early warning system

In the first phase of this project, which was completed in July 2007, we have identified a number of techniques. Prototypes for these techniques have been constructed and

tested (or being tested) in the sponsors’ laboratories. The main objective of Phase 2 are:

1. Analysis of the results of the prototype evaluations for the two hydrate monitoring techniques

2. Providing support & evaluation of the equipment constructed by commercial organisations

3. Integrating some of the techniques to existing commercial devices, where possible

4. The identification and development of one or more of the options for the Early Warning System

5. Facilitating the application of the data generated in supervisory systems

6. Moving towards on-line measurements for some of the techniques developed in Phase 1

7. Final screening prior to finalising the design for industrial scale production

8. Screening and evaluating some new techniques

Title: Hydrate Monitoring and Early Warning System

Sponsors Confirmed: BP, Chevron, NIGC, Petronas, Statoil, Total



Project No. : 4403 PPD OMAC ITF Funding (£k): 125 Duration (Months): 4

Summary: The initial work package is to understand the technical challenges set by the client and then to reproduce these challenges under controlled conditions. At this stage we will be

looking at first pass concepts and looking to understand the restraints laid down by the working environment. The aim is to understand the range of frequencies and penetration

depths that are most likely to achieve the project final goal. Once this has been completed and documented we are then ready to consider the material type of the transducer

and also the physical characteristics that it should embody for the application. Transducers size will be controlled by the manner in which we are able to cut the elements and in

the order in which they are placed. Upon successful completion of this section we will move to the first prototype head again with full documentation. Whist this is going on we

will be running a parallel project for the design and manufacture of the electronics module that will interface with the head. Once the two modules are complete then it is

intended that we move to a test phase in the USA and undergo intensive trials prior to repeating the exercise in front of the sponsors here in Aberdeen. Full document packages

and results will be available for independent study at this time.

Title: Acoustic Inspection Gauge

Sponsors Confirmed: Chevron

Project No. : 4411 PPD LUX Monitor™ ITF Funding (£k): 175 Duration (Months): 12

Summary: LUX Monitor™ is an exciting new technology platform that will offer significantly simplified, reliable methods for measuring several parameters important in oil production:

Oil-in-Water – much simplified, reliable method for measurement of oil-in-water content. LUX Monitor™ will significantly simplify the testing process and reduce costs associated

with testing

Water-in-Oil - will improve current methods by simplifying the testing process. Better Water-in-oil testing will ensure correct oil pricing by offering reliable results.

Droplet size – reliable measurements that will help optimise the separation and production processes suitable for testing at many points in system for comprehensive

information gathering

LUX Monitor™ feasibility study was completed with the support of ConocoPhillips in November 2007 with promising results proving the technical concept. LUX and

ConocoPhillips are taking this technology through to next phase of lab based development with a view to take it to a field trial upon successful completion of this project. LUX

and ConocoPhillips wish to invite other Operators to join this project and take LUX Monitor™ to the next stage.

Title: LUX Monitor™ - development of a novel technology platform with applications for measurement of Oil-in-Water, Water-in-Oil and Droplet size




Project No. : 4434 PPD SUREFLEX09 ITF Funding (£k): 180 Duration (Months): 8

Summary: In 2001 and 2002, two Oil & Gas UK guidance documents were created, namely:

1. State of the Art Flexible Riser Integrity Issues”

2. "Guidance Note on Monitoring Methods and Integrity Assurance for Unbonded Flexible Pipe”

These documents have been widely adopted by the industry on an international basis.

Considerable feedback has been received that these documents require updating as flexible pipeline and riser integrity is still a significant issue both for the UK continental shelf

and elsewhere around the world. Many new degradation and failure modes have emerged and the growth in use of flexible pipe has continued apace around the world. Hence,

the statistics of flexible pipe use along with degradation and failure mode description need updating. Also, best practice approach to monitoring and inspection of flexible

flowline, jumper and riser systems needs research and update.

It is intended that the work for this JIP, targeting 10-12 participants, capture international experience on the use and integrity management of flexible pipe. In this context,

participation from oil companies outside the UK sector will be sought. As part of this work, a comprehensive survey will be implemented with interviews and formal

questionnaires being performed with relevant contacts around the world. All data collected during this work will remain confidential to Oil & Gas UK, and only desensitized and

un-attributable information will be included in the revised documents.

A steering committee of the participants will be formed to guide the project and Oil & Gas UK intend to subcontract MCS to perform this work. As world experts in flexible pipe

technology, MCS provide an intelligent means to collate the right data and draw the best conclusions from the work performed. The outcomes of the work proposed will enable

best-practice integrity assurance of flexible pipe in addition to comprehensive statistics of damage and failure for future reliability analysis of new flexible pipe designs.

Title: Flexible Pipe Survey and Integrity Assurance Guidance Note

Sponsors Confirmed: BP, ConocoPhillips, ExxonMobil, HSE, Inpex, Maersk, Nexen, Petrobras, Shell, Statoil, Technip, Total, Woodside



Project No. : 4463 PPT NUC ITF Funding (£k): 239 Duration (Months): 9

Summary: - OPEX makes or breaks underwater work. All too frequently, The aim of the proposed project is to develop a novel cost effective underwater cutting device for use in

decommissioning. There are a number of potential benefits to proposed cutting in decommissioning scenarios:

(i) Non contact, no cutting reaction force, no oxidiser, no consumables required and no possibility of the tool sticking in the cut

(ii) Light weight cutting head

(iii) Flexible delivery system

(iv) Relatively low power required (cutting power density up to 100 x greater than electric arc systems)

(v) Complex cut geometries possible.

(vi) Cutting speed comparable with Abrasive Water Jet Cutting in air.

(vii) Autonomous, ROV and diver deployment are possible due to the low utility payload.

The project will have a phased approach. The work will start with underwater cutting tests using existing facilities at the University to develop a suitable underwater cutting

head design and to prove the viability of cutting in a variety of attitudes. Concurrently a more compact cutting system and deployment system will be developed based on the

outcomes of the initial tests.

Title: Novel Underwater Cutting

Sponsors Confirmed: BP, ConocoPhillips, Shell

Project No. : 4464 PPX ITF Funding (£k): 20 Duration (Months): 4

Summary: Polysiloxane based coatings, particularly those with a high phenyl content, are capable of operating at in excess of 250°C for many tens of thousands of hours. Polysiloxanes are

also used as additives to coating systems to act as binders, to reduce the surface energy which improves release properties or reduces fouling, to reduce the levels of volatile

organic compounds in the paint solution or to enhance long-term durability. For these reasons, coatings containing polysiloxanes are frequently used in the oil and gas industry.

There are many different types of polysiloxanes used to achieve these performance attributes. These are all based on well established products, which are used individually or in

combination. Simple silsesquioxanes are one such product, often referred to as silane coupling agents. The attribute of particular value is the presence of both organic and

inorganic components which allows them to react with both polymer and mineral/metallic groups or surfaces respectively. These coupling agents have historically been used to

enhance the bonding of coatings to the substrate. Reacting these coupling agents together to form stable oligomeric (small scale polymeric) structures gives the opportunity to

form novel additives for coatings and adhesives. Such oligomers have only been available for a few years and are typically available as high cost research grade materials.

TWI has developed and patented a new synthesis route for oligomeric silsesquioxanes, Vitolane® technology, making them more affordable. These oligomers can be designed to

have specific components with particular performance capabilities. Incorporation of these materials into coating or adhesive formulations can therefore confer these attributes

into the final material. This may yield coatings with a set of performance characteristics that are not achievable using more conventional materials.

Title: Preliminary Development of High Performance Coatings for the Interior of Pipes and Tubes




Project No. : 4543 PPX RAIDACT ITF Funding (£k): 50 Duration (Months): 6

Summary: The RAIDACT proposals offers oil-itf the opportunity to assess the feasibility of an exploration platform level system for detecting and characterising ice bergs, ice edges and

pollution using polarimetric radar techniques. The core of the system would be mounted on the exploration platform and would complement conventional navigation radar. A

highly compact transmitter/ transponder unit consistent with mounting on a small UAV (for ease of deployment and capture) could be deployed for characterising whether

approaching ice presented a threat to the platform.

The feasibility study will draw on SEA’s knowledge:

- of radar systems at all frequencies (from P to Ka)

- in multiple configurations (spaceborne airborne and bi-static/ monostatic)

- the potential UAV platforms that could cope with the Arctic environment.

RAIDACT will engage with the expertise of the exploration community that would use the system to capture what information is actually needed for operational decision making

and in what timescales. It will ensure that the proposed solution is complementary to information that can already be available on ice movement from other sources and provide

a fully costed way forward before proposing demonstration and field trialling of the solution.

Title: Radar for ice detection and characterisation

Sponsors Confirmed: ITF, Total

Project No. : 4545 PPD DOF ITF Funding (£k): 30 Duration (Months): 4

Summary: Digital Oilfield (DOF) programmes aim to improve business performance by harnessing evolutions in information based technologies. DOF helps people make better informed

decisions by providing them with real time information and the ability to work collaboratively with experts across the company when needed, irrespective of geographical

location. They exist because: -

- Production efficiency and total reservoir recovery must be maximised.

- The workforce is reducing in both numbers and experience, so scarce expert resources must be better utilised.

- As easy oil runs out, more complex, challenging production and drilling methods must be mastered, often in more remote, environmentally harsh locations.

DOF programmes can exploit lessons learnt in similar change initiatives in the defence sector.

For over a decade, the UK Armed Forces have been engaged in transformation programmes such as Network Enabled Capability (NEC) which utilise communications and

information technologies, enabling informed collaborative decision making. Increasingly, they are able to operate effectively as a cohesive, multi-disciplinary, global organisation

supported by a real time flow of information from sensor to decision maker.

The proposed study and workshops will explore how NEC experience can accelerate DOF implementation. It will help operators overcome many issues that they face today more

quickly and at lower cost. Ultimately, it will allow DOF initiatives to deliver increased business benefits.

Title: How can defence expertise and experience enhance Digital Oilfield initiatives?

Sponsors Confirmed: BG Group, BP, Dong Energy, Hess, Shell, Total



Project No. : 4575 PPX UPB ITF Funding (£k): 30 Duration (Months): 1

Summary: A UPB is a self contained, redeployable production system. It includes:

- 15, 000 bpd fluids production buoy (500 – 5,000 bopd)

- Three 0.85MW dual fuel gas/diesel engines

- Minimum configuration single well, with integrated production umbilical

- 200,000 bbl storage gravity base

- Tanker offload

- Unmanned production, access boat

- Sand and produced water clean-up and sea disposal

- No flaring, fuel gas with cold vent

This work has now concluded with a large part of this work being done in association with Ocean Resource Limited. Using existing technologies the UPB has the potential to

unlock up to seven billion barrels of oil from stranded assets in the UKCS from over 250 wells and opportunities. It also has the potential to generate key supplier and associated

construction employment.

Title: Unmanned Production Buoy

Sponsors Confirmed: ITF

Project No. : 4600 PPX SLT ITF Funding (£k): 75 Duration (Months): 4

Summary: This study will examine the technical feasibility of constructing segments of subsea pipeline onshore, towing these segments (over long distances) using snake modules and

installing the pipeline segments using Snake Lay Technology.

Title: Onshore Pipeline Fabrication and Tow Feasibility Study

Sponsors Confirmed: ITF, Woodside



Project No. : 4632 PPD UPTAKE Biofibre ITF Funding (£k): 70 Duration (Months): 4

Summary: Pipeline cleaning solutions ltd is proposing carrying out a proof-of-concept study for UPTAKE-BioFibreTM technology, which is a novel fluid that has the ability to suspend and

carry solid particles and liquid particles, and maintain them in suspension in order to move, remove or transport those particles.

UPTAKE-BioFibreTM also allows the pumping of solid particles such as sand, clay, gravel, paraffin wax pieces, black powder and other such solids, maintaining them in suspension

and not allowing them to settle out by gravity, thus blocking pumping, piping and tanks/vessels. The ability of UPTAKE-BioFibreTM to take in and suspend particles of solid

means that if passed through pipes, tubing, tanks, containers and separators it will remove those solids from vessels and piping.

In oil and gas production operations, UPTAKE-BioFibreTM increases the efficiency of the pumping process, allowing higher percentage of solid per volume of liquid, creating the

opportunity to pump at lower pressure and with increased efficiency. It should be possible to pump UPTAKE-BioFibreTM mixtures further distances and from greater depths and

to greater heights than is currently possible.

The fibres in UPTAKE-BioFibreTM make the mixture less abrasive than conventional solid/liquid mixtures which have to be pumped at high pressure, extending the life of valves,

pumps, separators, and metal containers and tubing.

The business case for UPTAKE-BioFibreTM is therefore based on an opportunity for increased production rates, and reduced maintenance costs/opex. Particular applications for

UPTAKE-BioFibreTM are anticipated in high sand production fields, mature fields, and subsea processing.

Title: UPTAKE-BioFibre Proof-of-Concept Study

Sponsors Confirmed: BP, ConocoPhillips, ITF, Weatherford




Summary: A feasibility study was commissioned by ITF and BP and carried out by TWI (TWI Project 18936 / ITF Project 4464PPX). This investigation established that multifunctional

silsesquioxanes could be produced and used to fabricate coatings that adhered to a primed metal substrate and provided an abrasion resistant coating with low surface energy.

Two curing mechanisms were investigated, thermally curing with amine hardeners and UV curing. The UV cured resins were typically more abrasion resistant but more prone to

cracking of thick layers and on accelerated ageing.

The project will evaluate a number of coating compositions and deposition methods and evaluate their relative performance. Specific targets will be aimed for in terms of

coating thickness and contact angle with water. Application related evaluation trials will be undertaken and reported.

A target deliverable is a single coating that is up to 100µm thick, well adhered without the use of a primer layer and that has a high contact angle with water. The final report will

detail the approaches trialled and the results of the corresponding evaluation programme, together with recommendations for any routes which show promise for further

development.

TWI will provide short interim monthly progress reports providing a statement of work undertaken, progress against plan and planned activities for the next period. If required,

an initial meeting will be held at TWI between TWI, ITF and any other sponsoring body identified by ITF. The final report will be presented to ITF and BP in a meeting to be held in

Aberdeen after the submission of a final report on the work.

Title: Continued Development of High Performance Coatings to Prevent Scale Accretion - Phase 1

Sponsors Confirmed:

Project No. : 9013 PPD An Mea ITF Funding (£k): 120 Duration (Months): 12

Summary: The Project (H&S) Core Group is working to develop and implement a Standard of Competence for Offshore Oil and Gas construction supervisors. Woodside wish to use the ITF

contract process and on behalf of the Core Group, has requested that An Meá prepare a commercial proposal for the Development Phase of the work.

Title: Develop Units of Competency that Establish Performance Criteria and Evidence Guides

Sponsors Confirmed: Apache, BHP Billiton, Chevron, Woodside



Project No. : 9068 PA ITF Funding (£k): 78 Duration (Months): 12

Summary: This work is a precursor to a follow-on proposal submitted in 2005 to apply the technology to specific field applications.

While reliability of controls and instrumentation hardware deployed on Subsea fields is expected to be very high, it is unavoidable that there are occasional failures. The

capability to detect failing sensors from raw data streams and to plan maintenance intervention based on this information is key to minimising OPEX. Once a sensor has become

unreliable it is also possible to derive the information previously provided by that sensor by other means, such as a virtual sensor.

Son-ix Technologies have developed technologies that can detect early failure of sensors, compensate for sensor drift and even replace the sensor completely with a virtual

model. Our solution is based upon the use of neural networks to model and predict the behaviour of sensors.

Title: Slickline Fatigue Project - Phase 2

Sponsors Confirmed: BP, Chevron, Total



Project No. : 9087 PA HETS ITF Funding (£k): 830 Duration (Months): 36

Summary: READ have successfully developed and field tested a Hydraulically Expandable Tubular System (HETS) Internal Patch for 7” tubular’s (casing, liner or tubing). The patch has many

applications such as water shut off or repair of tubulars (e.g. maintain integrity during TTRD drilling). The HETS system utilises high-pressure water (up to 30,000 psi) to expand

varying grades of steels (e.g. L80, P110, Stainless Steel etc.) by up to 30% on diameter. Through this application, READ propose to develop the system further to suit 5” to 5.5”

tubular’s.

The system will be capable of deploying variable length stainless steel patch’s (e.g. 4m to 14m) with variable wall thickness (currently 6mm) and has been successfully tested to

seal up to a differential pressure of 5000psi. The patch when set maintains maximum thru bore, the only restriction being the thickness of the patch. Maintaining maximum thru

bore provides least restriction for future well intervention tasks and causes minimal pressure drop when the well is placed back on production of injection.

The current HETS 7” patch tool can be run on Drill Pipe, Coil Tubing and currently being developed for deployment on Wireline with Statoil, enabling operations in either

overbalanced or live well conditions. The HETS system consists of a high pressure (HP) seal system, HP control unit, downhole pressure intensifier, various safety features,

downhole sensor recording and if run on wireline an electro hydraulic power pack with telemetry to surface.

READ have already developed and qualified a 9 5/8” and 14” HETS external patch service for Statoil and Talisman. Many other HETS solutions (for larger tubular sizes) are being

developed, such as expandable Liner Hanger systems for BP, expandable liner hanger systems for drilling with casing for ConocoPhillips and expandable Zonal Isolation Barriers

for Statoil. All of these solutions could be migrated for operation with the slim 5” to 5 ½” system.

This project will involve re engineering the HETS seal system (expected rating of 20,000 psi) and the electro hydraulics power pack to deliver the ability to deploy steel patches in

smaller well diameters 5”-5.5”. The project will include the design, manufacture and testing of a prototype tool for commercial operations.

The applications for this 5” internal expandable steel Patch service are:- Cladding corrosion damage, water shut-off, pre-conditioning production tubing – TTRD, drilling wear –

cladding etc.

Title: Hydraulically Expandable Tubular System (HETS) - EXPANDABLE METAL PATCH FOR 4.5" AND 5" AND 5.5" TUBING/LINER (Internal Patch)

Sponsors Confirmed: BP, Chevron, Maersk, Statoil, Total


Itf Closed Project List Dec 11

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Transcript of Itf Closed Project List Dec 11