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Founded in 2001, FEESA is a management and employee owned oil & gas engineering consultancy specialising in conceptual engineering studies and flow assurance.

FEESA’s consultants are recognised as amongst the best in the world. They are supporting operators of oil & gas developments with conceptual engineering and flow assurance studies in many economically sensitive locations, including the UKCS, offshore Angola and the Australian NW Shelf.

Whilst FEESA’s consultants are experienced users of the major transient and steady state flow modelling software, they have the advantage of Maximus, the company’s proprietary software.

Maximus is becoming recognised across the industry as a modern and user-friendly software suite for the rapid development of comprehensive and accurate models of upstream surface network scenarios through field life, thus facilitating confident decision making during the conceptual design phase of oil & gas field developments. It is also capable of building accurate models of production and injection systems for subsequent detailed flow assurance studies.

Model scenarios of oil & gas production systems are essential during the conceptual phases of field development. The subsurface and surface engineering options adopted have an enormous bearing on field economics. Scenarios provided by Integrated Production Modelling (IPM) have been demonstrated to provide a valuable decision making “hub” during this critical phase of a project.

FEESA consultants work with an operator from the earliest stages of project feasibility mapping, through FEED. Early feasibility mapping usually begins before there is a mature reservoir model, and our consultants will work with key operator personnel to build accurate and user friendly life of field model scenarios using Maximus, with output either in the form of engineering or economic performance criteria, possibly linked to the terms of production sharing or gas sales contracts. As conceptual engineering develops towards FEED, the Maximus reservoir module can be substituted by links from market leading reservoir simulators, and during FEED the Maximus model can still be used by the operator as a management tool, which “binds together” the different detailed models involved in the development project.

Detailed flow assurance and optimisation analysis can be undertaken by FEESA’s consultants using Maximus, either as a steady state flow simulator, or by links to an industry standard transient flow simulator.

FEESA’s skills cover the full-range of flow assurance requirements, including:

Steady State Thermal Hydraulic ModellingSteady state modelling of multiphase well, pipeline and riser systems using advanced engineering tools such as Maximus software. FEESA’s consultants are able to develop comprehensive and accurate models of converging, diverging and/or looped production and injection systems including the selection of appropriate inflow performance relationships for modelling reservoir flows.

Deliverability ModellingUsing Maximus as an Integrated Production Modelling (IPM) tool, FEESA has performed numerous studies for major clients to investigate deliverability and production. Building a model from the reservoir to the facilities, we have looked at the effects of tubing and pipeline size, multiphase boosting, gaslift injection, subsea separation and various novel technologies such as hydrate slurry flow on the production rates achievable from a given configuration. By investigating a large number of system permutations, clients have been able to use the production profiles generated by Maximus to perform comparative economic selections, thus identifying the optimal configuration.

Transient Multiphase ModellingWith the increasing flow assurance challenges encountered with deepwater developments and long-range subsea tiebacks, transient multiphase flow simulation has become a standard technique for investigating system behaviour and operability. FEESA’s consultants have developed considerable experience in this area with both Scandpower’s OLGA and analytically derived methods, where appropriate. This experience has been developed via a number of projects including some high profile deepwater developments.

Flow Assurance Operability StudiesThe key to the successful use of steady state and transient modelling is interpreting the results into a comprehensive Operating Strategy. FEESA has gained considerable experience in the evaluation of flow assurance operability of dozens of complex production networks. Results from thousands of simulations can be compiled to develop Operating Guidelines that are comprehensive enough to be Peer Reviewed, yet still intelligible by other disciplines.

FEESA Consultancy Services with Maximus

OUR BACKGROUND

THE FEESA LTD. FA ADVANTAGE

FEESA ASSURANCE

Westmead House, Farnborough, Hampshire, GU14 7LP, UK Tel: +44 (0) 1252 372 321 - Email: info@feesa.net

www.feesa.net2

Issues typically addressed are terrain induced slugging, hydrate, wax and asphaltene prevention and remediation, thermal control, production boosting, erosion/corrosion and complex rheology, amongst others.

Specialist Fluid Flow StudiesFEESA’s consultants have a detailed understanding of the fundamentals of fluid flow and heat transfer which has been put to good effect on a number of specialist fluid flow studies. These have included the analysis of sand transportation in multiphase flows, the evaluation of erosion effects due to particulate transfer, the modelling of non-Newtonian flows in gelled oil systems, hydrate slurry transportation and the investigation of jetpump (ejectors) hydraulics in a gas-field development.

In the ten years from formation, FEESA has successfully executed numerous flow assurance studies for major clients. Brief details of these projects are listed:

Amerada– Chestnut Development, UKCSPerformed parametric transient studies of various tieback alternatives for the Chestnut field. Transient analysis was performed using OLGA and examined cooldown and stability behaviour.

BP - Angola Programme Appraise/Select ProjectsBP’s Flow Assurance consultant of choice during the conceptual phases of six deepwater developments offshore Angola. This involved numerous OLGA and Maximus IPM and Flow Assurance studies to verify the deliverability, thermal performance and operability of hundreds of proposed configurations in collaboration with BPs reservoir engineers. Key to these projects was the development of Hydrate Management Operating Guidelines.

BP / CBI - WREPDevelopment of a pipeline leak assessment model for the 820km Western Route Export Pipeline from Baku to Supsa. The model allows easy assessment of the maximum leak from the pipeline in the event of failure of old / degraded (FSU) pipe during a the de-oiling process prior to linepipe replacement.

BP EPTG– Cold Flow ModellingApplied Maximus™ to model BP/SINTEF’s novel Cold Flow process. This included the simultaneous modelling and simulation of up to seven coexistent phases in the pipeline transportation system, including gas, oil1, oil2, water, hydrate I, hydrate II and ice. The simulations were performed to optimise on tubing/pipeline sizes, subsea multiphase boosting requirements and subsea free water separation.

BP- WNDTaken over complex flow assurance work from a major contract company where they were unable to meet the clients needs. Developed a complex Maximus model to investigate line sizing for a 40 well gas production network tied back via three trunk lines and a central processing facility. Use of the model to perform statistically based analysis to optimise MEG injection requirements to avoid hydrate formation. In parallel, develop an OLGA model of the system and assess restart behaviour and slug catcher sizing.

BP- Greater Plutonio FEED Study, AngolaDeveloped the flow assurance strategy for BP’s Greater Plutonio Block 18 Development, offshore Angola. This work included life of field steady state and transient studies to prove that the project could operate successfully using conventional wet insulation and a manageable sized slugcatcher.

CalEnergy- Anglia NW Tieback, UKCSPeer Review of previous flow assurance studies, leading to the development of an integrated reservoir LOF model. This model was used to evaluate the effect of backout of existing wells and the requirements for hydrate inhibitor injection.

Chevron- Caledonia Development, North SeaConstructed steady state and LOF models to investigate tieback options for the Caledonia field. Analysed different production enhancement options including subsurface ESPs, gaslift injection and subsea multiphase boosting. Performed parametric transient simulation studies using OLGA to evaluate slugging and cooldown behaviour.

CoP EnochdhuDeveloped a Maximus model to investigate line sizing for tie-back to an existing production system. Demonstrated to the client the future instability of their existing wells and the need for careful management of gas lift rates.

ConoccoPhillips US - Large Offshore Gas SystemDeveloped a model to investigate the trade off between drilling and offshore compression for a large offshore gas system using Maximus. MEG injection rates were predicted on the fly to ensure hydrates were avoided throughout time in the entire network.

ENI/KDPC- Kashagan Development, KazahkstanConsultancy to the ENI/KDPC design team for the flow assurance design of the Kashagan development. Made best use of numerous OLGA results previously generated by third party consultants to develop Operating Guidelines and focus future transient studies.

Consultancy Services with Maximus

SELECTED PREVIOUS PROJECTS

Gaz de France - Anglia NW Tieback, UKCSA study to evaluate the sensitivity of LOF predictions to the well completion assumptions, including producing length, permeability and skin factor. The analysis also included refined hydrate inhibitor injection requirements taking account of pressure evolution through field life. Simulations were performed with a third-party simulator and Maximus.

Westmead House, Farnborough, Hampshire, GU14 7LP, UK Tel: +44 (0) 125 237 2321 - Email: info@feesa.net

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Masons - Expert Witness SupportProvided expert witness services to the legal firm Masons acting on behalf of a consortium of Oil Companies. Advice given in the design, optimisation and operation of ultra- long oil transportation pipelines with intermediate pumping stations.

PetroCanada - Guillemot West Extension, UKCSFlow assurance services to the Veba WEP team, concentrating on the production chemistry implications of bringing a higher CO2 fluid into a carbon steel production system.

Saipem - Support to Subsea Design Team, FanoProvided flow assurance support to Saipem’s subsea design team based in Fano Italy across a range of projects, including a deepwater project in the Gulf of Mexico.

TMF - Multiphase R&DSponsors and participants of the Transient Multiphase Flow R&D Programme directed by Professor Geoff Hewitt of Imperial College, London. Carried out two separate reviews of active slug control systems and non- Newtonian flows. Also interfaced Maximus to the research code TRIOMPH to allow integrated transient slug prediction.

Woodside - Great Western Flank DevelopmentDeveloped several Maximus IPM models for Woodside to carry out a conceptual study of a ~20 reservoir gas development on the North West Shelf of Australia. Numerous development strategies were investigated, with a potential of up to three compression platforms in a simulation and the tieback to existing brown field developments. Models were validated against data from the brown fields and a new method for modelling the reservoirs and wells were added by request from Woodside.

Woodside - Chinguetti Development, MauritaniaFlow assurance peer review for the deepwater heavy oil Chinguetti development, offshore Mauritania. Used Maximus to develop a model of the Chinguetti production systems from the reservoir to the FPSO. Supported the Woodside team in the liaison with the FPSO and topsides contractors.

Martin Watson (Director)Martin holds a PhD in Multiphase Flow from Imperial College London. He subsequently worked on a number of field developments as a flow assurance engineer for Granherne before co-founding FEESA. Martin specialises in IPM modelling, transient multiphase flow analysis and the development of Flow Assurance Operating Strategies and Guidelines. Martin has developed significant experience in Deepwater gas-oil developments, in particular BP’s Deepwater Angola Programme and has also worked on several large gas gathering networks.

Neil Hawkes (Director)Neil holds a PhD in Multiphase Flow from Imperial College London. He subsequently joined Baker Jardine & Associates where he was responsible for the development of a novel Life-Of-Field simulation tool called Pipesim-FPT, now marketed by Schlumberger. While at Baker Jardine, he also performed a number of consultancy studies for clients such as PDVSA, PEMEX, BP and Norsk Hydro. Since co-founding FEESA, Neil has been responsible for the development of the Maximus integrated production modelling tool. He has used his indepth knowledge of IPM in detailed modelling studies for BP Angola and Woodside Australia.

Adrian Johnson (Consultancy Manager)Adrian holds a PhD in complex fluid mechanics from the University of Surrey and is a Chartered mechanical engineer. He worked for 10 years in BP in R&D, pipeline engineering / flow assurance and was the company specialist in the use of DRA. Subsequent to BP, Adrian became a freelance consultant in pipeline hydraulics and flow assurance for 11 years, before joining FEESA as Consultancy Manager at the beginning of 2010. Adrian manages a growing team of flow assurance specialists based in Farnborough, working on projects ranging from bespoke modelling of production systems and pipelines through to complex production network models using the in-house Maximus IPM and FA software as well as transient software.

Consultancy Services with Maximus

KEY TEAM OF CONSULTANTS

Woodside BrowseSecondments into both the client and the flow assurance contractor’s team to help drive the Flow Assurance efforts of this ~£30 billion waxy LNG development. Built a Maximus model of the whole production system to investigate life of field thermal hydraulic and compositional issues, including the optimisation of the MEG injection system and corrosion management.

Justin Alexander (Deputy Consultancy Manager)Justin holds an MEng in Chemical Engineering from Imperial College London and is a Chartered Chemical Engineer. He worked for 17 years for UK-based engineering contractors, managing process design teams on conceptual studies and FEED projects for major oil and gas projects for clients including ExxonMobil, Chevron, Total, Saudi Aramco and BP. Justin joined FEESA in 2012 as Deputy Consultancy Manager, to support Adrian’s management of FEESA’s fast growing team of flow assurance consultants, and takes the lead role on a variety of consultancy projects including flow assurance studies, complex production network modelling, and CO2 injection network modelling.

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IPM FA FIELD DEVELOPMENT MODELLINGDATA REQUIREMENTS CHECK LIST

•ReservoirWhether you’d like to model it as a look-up table

(simplest and perhaps good first step) or as a tank model.

If a tank model, we’d need an Area/Depth Table of the reservoir, and where the gas/oil and oil/water interfaces are at these depths. Net to Gross, Porosity, Compressibility of the Pore Volume, and the satura on and compressibility of the connate water, whether it’s one tank or a network of tanks, any preferences on how you’d like to model aquifer support, water injec on, if there is any.

•WellsDrilling Schedule.

Tubing geometries (MD’s & TVD’s if you have them, or just step out distances and comple on depths if you don’t), internal diameters.

• Flowline Descrip on (drawing?) of the flowline network.

•Func onality Any ar ficial li methods you are keen to inves gate.

•Topsides First stage separator pressure (constant or a func on

of gas rate or me, etc).

Sufficient informa on to calculate an equivalent lengthof Topsides pipeing to the first stage separator pressure.

OIL AND GAS CHECKLIST

GAS SYSTEM DATA CHECK LIST

• ChokesAny maximum or minimum well constraints you’d liketo i mplement.

• Flowline Diameters, lengths, eleva onal profile informa on and

insula on specifica ons of any flowlines and risers.

Descrip on (drawing?) of the flowline network.

•Func onalityA brief descrip on of the system and the ques ons

you’d like answers to.

Any other concerns, flow assurance, erosion, etc.

•Topsides Informa on on any total system constraints

(e.g. maximum oil/liquids/water/gas processing rates).

•Reservoir Composi on informa on on the gas and produced

water (if this is anything other than condensed water)and inhibitor (MEG, methanol?)

Whether you’d like to model it as a look-up table (simplestand perhaps good first step) or as a tank model.

If a look-up table (aka decline curve); we’d need a table ofhow the reservoir pressure, composi on (if appropriate)changes with cumula ve gas produced (we could backcalculate this from a produc on profile, if you alreadyhave one from a reservoir simulator).

Unless requested otherwise, we’d model the gas leavingthe reservoir (upstream of the inflow peformancerela onship) as being saturated with water at reservoirtemperatures and pressures; if the gas drops into the twophase region the condensate will also be le behind inthe reservoir, i.e the produced gas will lean out over me.

•Reservoir Composi on or black oil characteris cs (GOR, etc) plus

any composi onal and/or physical property informa onabout the connate water.

If a look-up table (a.k.a. decline curve); we’d need atable of how the reservoir pressure, composi on (orGOR & watercut) changes with cumula ve oilproduced (we could calculate this from a produc onprofile, if you already have one).

Reservoir temperature at a specified depth.

Reservoir temperature and pressure at a specified depth.

•Wells Preferred Inflow performance rela onship (IPR) for the

wells; either one of the published models or a userdefined equa on. Our current list of gas related IPRs are;”Gas Back Pressure”, “Gas Forchheimer”, “Gas PI”, “GasPseudo Steady State”, “Gas Radial Flow Equa on”, “GasSpecific PI”, though we could add more if required.

Tubing geometries (MD’s & TVD’s if you have them, orjust step out distances and comple on depths if youdon’t), internal diameters and roughnesses.

•Wells Preferred Inflow performance rela onship for the wells(either one of the published models or a user definedequa on).

•Topsides First stage separator pressure (constant or a func on of

gas rate or me, etc). Sufficient informa on to calculatean equivalent length of Topsides pipeing to the first stage separator pressure.

OIL SYSTEM DATA CHECKLIST