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Amf14 brochure a4

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  • 1. ARGENTINA’S ONLY OPERATOR LED CONGRESS FOCUSED PURELY ON MATURE FIELD PRODUCTION OPTIMIZATION Optimizing Artificial Lift And Secondary Recovery Injection To Maximize Production And Reduce OPEX In Argentina’s Depleted, Multi-Layered Oil And Gas Reservoirs Key Issues To Be Discussed Include: July 23-24 | Buenos Aires | Argentina Damian Ramallo Leader Of Production Gran Tierra Energy Expert Insight From Argentinean E&P Operators Working In Mature Fields, Including: M Follow Us: @UnconventOilGas www.mature-fields-argentina-2014.com • ARTIFICIAL LIFT TECHNIQUES - LIGHT OIL: Selecting the optimal artificial lift techniques based on run life, cost, durability, energy consumption and effectiveness to optimize production within low-pressure reservoirs • VISCOUS OIL PRODUCTION: Defining the optimal well design to ensure the effective production of fields with viscous oil properties • GAS PRODUCTION: Examining the latest technologies to deliquify gas wells and improve the run life of gas lift production • SURVEILLANCE & MONITORING: Identifying production monitoring, automation and chemical tracer technologies to optimize injection and minimize failures • FAILURE MITIGATION: Preventing well failures through sand, paraffin and corrosion control methodologies, treatments and technologies • WATER & POLYMER INJECTION: Delivering water and polymer injection and waterflooding chemical treatment best practices to maximize oil and gas recovery Victor Perusini Head Of Production San Jorge Petroleum Francisco Queralt Head Of Facilities & Construction Americas Petrogas Alejandro Ameglio Production Superintendent Apache Argentina Carlos Laluf Head Of International Engineering Operations Azabache Energy Oscar Orellana Production Supervisor Total Martín Ignacio Kennedy Production Engineering Technical Consultant Petrobras Argentina Diego Garzon Duarte CEO Oilstone Energy EARLY LOCAL RATE Register By Friday May 30 SAVE $2700ARS
  • 2. Sheraton Buenos Aires Hotel & Convention Center San Martin 1225-1227 Buenos Aires 1104 Argentina Phone: (54) 11 - 4318 9000 Website: http://goo.gl/YKCKKA Venue Information: If Argentine production declines were improved by mere percentage points, the country’s production could increase substantially, adding enough crude recovery to fuel the entire country for years to come. With the global average recovery factor in a mature field sitting at only 20-40% for oil and 70% for gas, much of the country’s assets remain untapped. Considering production optimization can increase incremental production by up to 25% and EOR applications up to 70%, operators are acutely focused on adopting the right production technologies and strategies for application in these fields. The answer lies in optimizing production techniques and EOR; the initial investment into which can be far lower than exploration and workover efforts, while delivering some of the highest returns. A modest 1% improvement in recovery could potentially deliver millions of dollars in added value to a company’s assets; YPF is just one company that agrees, stating that waterflooding can improve recovery by 6-8%, with polymer injection recovery forecasted to be even higher at 12-16%. Mature Fields Argentina Production Optimization 2014 is the first congress of its kind addressing how to select the optimal lift method to maximize reservoir production in light oil, heavy oil and gas fields. The congress will deliver best practices on artificial lift, production monitoring, deliquification, sand control, corrosion control, paraffin control and EOR. Over two days, attendees will benefit from 20 operator case studies specifically focused on how to reduce OPEX and maximize production in fields with a high water cut. The mission of the congress is for Argentinean operators to take away usable solutions focused on how to maximize the run life of the well and prevent well failures through field automation, surveillance, monitoring technologies, lift selection and optimization and secondary recovery applications. The First Congress Focused On Increasing The Ultimate Recovery Of Argentinean Mature Fields With Minimal Resources: • Evaluates how to select the most effective artificial lift for light and heavy oil reservoirs to maximize production results in depleted reservoirs • Identifies how lifts and deliquification processes can maximize recovery and minimize drowning gas fields • Delivers real-life case studies on how operators have not only prevented well failures but rectified sand, corrosion and paraffin issues downhole ARGENTINA’S FIRST MATURE FIELDS CONGRESS FOR PRODUCTION AND RESERVOIR PROFESSIONALS Jane Thomas + (1) 800 721 3915 jane.thomas@lbcg.com ToSecureYourBoothOrDiscuss Tailor-MadeSponsorshipPackages,Contact: Sponsorship And Exhibition Opportunities Available At The Congress Need to generate new sales leads, launch a new product, engage key decision makers, build new future business relationships in key markets, or simply educate the industry about a new product? Then you need to exhibit at the Mature Fields Argentina Production Optimization 2014. Our busy exhibit area is an integral part of the congress and is of genuine practical value to delegates, who are looking for new solutions and technologies. Exhibiting at the congress will help you position yourself as a market leader and centre of excellence to the key decision makers in the industry. For further information, please contact: customerservices@lbcg.com or + (1) 800 721 3915 www.mature-fields-argentina-2014.com (1) 800 721 3915 customerservices@lbcg.com EARLY LOCAL RATE Register By Friday May 30 SAVE $2700ARS
  • 3. ARTIFICIAL LIFT OPTIMIZATION, VISCOUS OIL PRODUCTION AND GAS LIFT OPTIMIZATION Day 1 Wednesday, July 23 8.30 Chair’s Opening Remarks KEYNOTE: ARTIFICIAL LIFT SELECTION 8.40 How To Select The Optimal Artificial Lift System For The Reservoir To Maximize Production Within Argentina’s Mature Fields: Case Study • Understanding how the presence of gas, liquids, sands and solids impact which artificial lift would optimize production • Comparing pulling index results from artificial lift systems to select the rig that will minimize interventions in gas and oil fields • Defining the optimal reservoir to use ESP, PCP, plunger lift and manual bean pump units to increase the run life of the well • Comparing the average run life of artificial lift systems to ensure the OPEX will not exceed the oil recovery DiegoGarzonDuarte,President,OilstoneEnergy 9.10 Question & Answer Session ARTIFICIAL LIFT - LIGHT OIL SELECTING THE OPTIMAL ARTIFICIAL LIFT TECHNIQUES BASED ON RUN LIFE, COST, DURABILITY, ENERGY CONSUMPTION AND EFFECTIVENESS TO OPTIMIZE PRODUCTION WITHIN LOW PRESSURE RESERVOIRS BEAM PUMP OPTIMIZATION PANEL 9.20 How Operators Are Reducing Paraffin And Gas Failures And Energy Consumption In Beam Pumps To Reduce OPEX • Assessing optimal beam pump velocity to prevent downhole breakages whilst maintaining the maximum level of production • Identifying the optimal beam pump for use in wells with high gas content to prevent gas interference, downhole failures and increase run life • Selecting the optimal beam pump when producing in deep wells to ensure the liquid can be lifted to surface efficiently • Comparing ceramic and steel beam pumps to assess the optimal system for preventing corrosion in high temperature wells PabloChebli,VPArgentina,CentralResources 9.50 Question & Answer Session 10.00 Morning Refreshments In Exhibition Showcase Area JET PUMP OPTIMIZATION 10.30 Evaluating Jet Pump Applications In Wells With A Depth Of 4000m With A Temperature Of 173°C To Define The Optimum Operating Regime In Mature Light Oil Wells • Analyzing the optimal surface pump, motor and power oil conditions when using jet pumps in light oil fields • Evaluating the installation costs, failure rates and production rates of jet pumps to identify production economics of the project • Examining pump efficiencies and run life to identify if running a jet pump will produce a well more efficiently than beam pump units • Identifying the optimal temperature for running a jet pump to ensure a polymer can be selected that will withstand the downhole conditions Moderator:DamianRamallo,ProductionLeader,Gran TierraEnergy SergioFlores,ProductionEngineer,GranTierraEnergy 11.00 Question & Answer Session ARTIFICIAL LIFT INNOVATIONS: CASING PLUNGERS 11.10 Validating The Application Of A Plunger Casing System In The Neuquina Basin To Evaluate The Potential For Improving Recovery In Low Gross Production Wells • Evaluating how to power the production system by using the energy generated in the well to minimize operating costs • Applying a production system to wells with medium/ high gas to liquid ratios to maintain fluid production in low production grossing wells • Defining the optimal casing diameter used in the Medanito reservoir to define the optimal apparatus and materials needed for successful application • Defining the capital costs of the tubing and sucker rod pump to evaluate if replacing the pumping system will be economical NicolasCuestas,ExtractionEngineer,PetrobrasArgentina MartínIgnacioKennedy,TechnicalAdvisor,Petrobras Argentina 11.40 Question & Answer Session LIGHT OIL: ARTIFICIAL LIFT SELECTION 11.50 Evaluating The Optimal Artificial Lift Selection Across The Life Of A Well To Minimize Production Losses • Evaluating geological characteristics of the reservoir including fluid distribution to define the optimal production system • Analyzing geological, economic and workload factors to select the optimal artificial lift system • Assessing depressurization to evaluate the impact on natural upwelling VictorPerusini,HeadOfProduction,SanJorgePetroleum 12.20 Question & Answer Session 12.30 Lunch In Exhibition Showcase Area HEAVY OIL PRODUCTION OPTIMIZATION DEFINING THE OPTIMAL WELL DESIGN TO ENSURE THE EFFECTIVE PRODUCTION OF FIELDS WITH VISCOUS OIL PROPERTIES MANAGING LOW PRESSURE WELLS 1.30 Selecting Optimal Surface And Downhole Equipment To Ensure Mobility Of Viscous Oil Within Wells With Low Production • Describing how surface lines have been optimized to improve the mobility of viscous oil from the wellhead to battery • Identifying the optimal pumping unit design to maximize heavy oil fluid production and reduce the failure of the pump • Evaluating how friction reduction chemicals improve the fluid movement of viscous oil and reduce wellhead to battery pressure JuanMiguelLinares,ProductionManager,Sinopec Argentina AldoSarelli,HydrocarbonProcessingEngineer,Sinopec Argentina FedericoG.Porta,IndustrialEngineer,SinopecArgentina JoaquínVaz,IndustrialEngineer,SinopecArgentina 2.00 Question & Answer Session GAS PRODUCTION OPTIMIZATION EXAMINING HOW THE LATEST TECHNOLOGIES ARE BEING USED TO COST TO EFFECTIVELY DELIQUIFY WELLS AND IMPROVE THE RUN LIFE OF GAS LIFT DELIQUIFICATION 2.10 Assessing How Capillary Technology, Chemical Injection, Plunger Lift And Polymer And Soap Agents Are Being Used To Control Water Downhole • Assessing how capillary technology and chemical injection can control water in the bottom hole to prevent wellhead pressure decreases • Assessing the advantages of using a plunger lift systems to deliquify the well and prevent workover costs • Identifying wellhead pressure and production symptoms to forecast wells with a high liquid ratio early on and prevent drowning • Assessing how utilizing polymer and soap agents can extract water from reservoir channels without removing the water from the well • Identifying the most efficient gas separator to ensure a technology is selected which does not allow a liquid presence GustavoGonzales,ProductionEngineer,Capsa-Capex 2.40 Question & Answer Session 2.50 Afternoon Refreshments In Exhibition Showcase Area ESP 3.20 Identifying How ESP Lift Is Being Used To Simultaneously Improve The Run Life Of Low Pressure Wells And Minimize Energy Consumption • Evaluating the optimal reservoir pressure and gas- liquid relationship for ESP to ensure the system can optimize production within the reservoir • Defining the optimal reservoir pressure and temperature when using an ESP to optimize the pump life • Examining methods for reducing downtime due to electrical stop • Assessing the application of magnet motor and speed drive technology to reduce energy consumption whilst pumping • Predicting the capacity of the ESP to run within deep wells to prevent costly interventions and reduce failure • Evaluating the optimal pump for use with various casing diameters to ensure the pump is adequately protected • Evaluating real time ESP production data to identify how the pump system is impacting the reservoir run life • Describing the efficiency of the gas lift system at each stage of the pump to identify stages where energy consumption can be reduced and gas production can be increased 3.50 Question & Answer Session GAS FIELD: LIFT SELECTION 4.00 Evaluating Artificial Lift Management In Mature Oil Fields To Ensure The Right Lift Is Selected, Installed And Monitored • Evaluating the selection, acquisition, installation, evaluation, monitoring and inspection of lift methods to adopt a multidisciplinary approach to lift selection • Analyzing how understanding the location and culture of the fields will impact the gas production optimization and cost of operations • Assessing how production optimization requirements change over time to identify when waterflooding and EOR projects are required MarceloHirshfield,OPOGC,Pemex 4.30 Question & Answer Session SURVEILLANCE IDENTIFYING PRODUCTION MONITORING AND AUTOMATION TECHNOLOGIES TO IMPROVE THE EFFECTIVENESS OF ARTIFICIAL LIFT AND MAXIMIZE RECOVERY PUMP OFF CONTROLLERS 4.40 Analyzing How Pump Off Controllers Are Being Installed And Maintained To Extend Run Life And Mitigate Downhole Failure • Providing a case study of how pump off controller automation has fixed a well problem and prevented workover and intervention costs • Explaining the installation and maintenance costs for pump off controllers to calculate the monthly cost of surface automation • Analysing how the automation of production levels, fluid levels and production weight controls can prevent pump breakages and surface leaks • Assessing the accuracy of using pump off controllers to fix well issues to evaluate if the system should replace previous monitoring and well maintenance methodologies • Evaluating how combining SCADA and the pump off controller has minimized beam pump failure through more efficient data management JuanMiguelLinares,ProductionManager,Sinopec Argentina AldoSarelli,HydrocarbonProcessingEngineer,Sinopec Argentina FedericoG.Porta,IndustrialEngineer,SinopecArgentina JoaquínVaz,IndustrialEngineer,SinopecArgentina 5.10 Question & Answer Session 5.20 - 6.20 Networking Drinks Reception In Exhibition Showcase Area EARLY LOCAL RATE Register By Friday May 30 SAVE $2700ARS www.mature-fields-argentina-2014.com (1) 800 721 3915 customerservices@lbcg.com
  • 4. MITIGATING FAILURES, WATER AND POLYMER INJECTION Day 2 Thursday, July 24 8.30 Chair’s Opening Remarks PREVENTING FAILURES UNDERSTANDING HOW FAILURE ANALYSIS, SAND, PARAFFIN AND CORROSION CONTROL IS PREVENTING WELL INTERVENTIONS AND WORKOVERS FAILURE ANALYSIS 8.40 Outlining How Production Monitoring Techniques Are Being Used To Predict Equipment Failure And Prevent Intervention And Workover Costs • Determining the most common causes of failure in wells to prevent failure in the pump, rod, surface and facilities • Explaining how a downhole failure analysis program can determine the accurate run life of a well and calculate the pulling-intervention index • Defining how failure analysis data software has improved the well run life AlejandroAmeglio,ProductionSuperintendent,Apache Argentina 9.10 Question & Answer Session SAND CONTROL 9.20 Assessing How Gravel Packers, Sand Filters And Sand Screens Are Removing Sand Cost-Effectively And Preventing Well Failures • Defining how the percentage of sand within the reservoir effects pump selection to optimize production within high sand content reservoirs • Comparing artificial lifts and gas lift pumps’ ability to handle sand content to determine the optimal pump for use when producing solids • Assessing the pulling index to determine if the sand should be removed from the reservoir or if the pump can operate without intervention • Outlining how gravel packing is being used to contain the sand in the well and prevent sand cleaning interventions 9.50 Question & Answer Session 10.00 Morning Refreshments In Exhibition Showcase Area PARAFFIN CONTROL 10.30 Analyzing Optimal Conditions In Which To Utilize Paraffin And Asphaltene Management Chemicals To Prevent Stuck Pipe • Outlining the optimal chemicals for reducing paraffin blockages downhole to maintain well performance and production • Determining how deep the paraffin disperser should be injected to avoid paraffin blockages within the tubing string • Identifying casing and chemical suites that handle paraffin to prevent downhole bottlenecks • Providing chemical deposition analysis results to determine if the chemical has worked effectively to remove the paraffin downhole • Evaluating the options for handling paraffin downhole and at the wellhead devices to avoid depositions and minimize interventions OscarOrellana,ProductionSupervisor,Total 11.00 Question & Answer Session CORROSION CONTROL 11.10 Evaluating The Type, Cost And Volume Of Chemical Treatments Being Used To Combat Surface And Downhole Corrosion And Prevent Pipeline Failures And Interventions • Assessing chemical reaction and equipment injection points to identify the optimal location for the chemical product to combat corrosion • Analyzing the optimal injection rates for corrosion chemicals to ensure target layer is reached • Evaluating the volume and cost per barrel of corrosion chemical treatment required to determine if well replacement is more economical than treatment • Explaining the chemistry composition of the corrosion control treatment to define how the chemical will tackle corrosion downhole • Evaluating the fluid characteristics, temperature and pressure of the well to select a treatment which will minimize corrosion effectively JuanManuelGarro,CorrosionEngineer,Pluspetrol 11.40 Question & Answer Session 11.50 Lunch In Exhibition Showcase Area CORROSION CONTROL METHODS 12.50 Identifying The Optimal Corrosion Control Methodologies Across The Most Problematic Areas Facing Corrosion Within Well Design • Sucker rod corrosion: evaluating key methodologies for preventing pump corrosion within high salinity wells to minimize well failures • Flow line corrosion: identifying a chemical treatment that effectively combats oil, gas and sulphuric acid corrosion to prevent pipeline breakages • Tubing corrosion: how an operator has evaluated the tubing pigments downhole to select a chemical treatment which will prevent H2S and CO2 equipment failures • Capillary injection corrosion: examining if wells can remain productive with paraffin downhole to determine if chemical investment is required • Bacteria corrosion: classifying corrosion chemical treatments within production facilities over 10 years old • Water quality corrosion: understanding how to effectively run chemicals from the surface to downhole to extend the run life of the rod and pump OscarOrellana,ProductionSupervisor,Total 1.20 Question & Answer Session INTERVENTION 1.30 Minimizing Non-Productive Time During Interventions To Reduce The Cost Of The Workover Operation • Identifying how to reduce standby times within intervention operations to reduce the cost of the workover • Defining the technical limit for workover operation drilling services to prevent complex workover operations damaging the economics of a well CarlosLaluf,HeadOfInternationalEngineeringOperations, AzabacheEnergy 2.00 Question & Answer Session INJECTION EXAMINING THE EFFECTIVNESS OF WATER AND POLYMER INJECTION, WATERFLOODING, CHEMICAL TREATMENTS AND CHEMICAL TRACERS IN OPTIMIZING SECONDARY RECOVERY WATER INJECTION PANEL 2.10 Evaluating Injection Assembly And Reservoir Dynamics To Ensure Waterflooding Optimizes Sweep Efficiency Within Multi-Layered Reservoirs • Evaluating injection pressure, volume and length of time to inject the reservoir to identify the optimal design for optimizing recovery • Quantifying injector pressure variance across fields to identify the pressures that led to maximum recovery increases • Qualifying the optimal flow injection rate and water shut off point to identify if lower or higher flood rates will improve recovery factor • Identifying the optimal point within a well’s run life to stimulate the reservoir to prevent production decline • Selecting how many reservoir layers should be flooded simultaneously to assess what is the optimal injection vertical sweep efficiency • Calculating the cost of a waterflooding project; estimated well run life and investment cost to determine if well replacement is more cost effective • Identifying methodologies for perforating thin waterfields layers to prevent waterflooding all layers and damage overall well recovery FranciscoQueralt,HeadOfFacilities&Construction, AmericasPetrogas 2.40 Question & Answer Session 2.50 Afternoon Refreshments In Exhibition Showcase Area WATERFLOODING WATER TREATMENT 3.20 Defining The Optimal Water Quality And Volume Needed For Flooding To Calculate Treatment Requirements And Costs • Defining the minimum water injection quality which is compatible with the reservoir to prevent corrosion, scale and bacteria in the pump, rod and tubing • Understanding the level of brine water solid and gel removal for recycling to reduce the volume of fresh water sourcing required for waterflooding • Evaluating how water treatment chemistry can be matched to water qualities to avoid surface and downhole decomposition • Defining the water treatment plants, floatation units and chemicals required to reduce ion and sulphur content and water salinity • Analyzing how electricity changes within the water can be used to separate the water and corrosion materials to prevent deposition • Comparing the cost per barrel of treatment to the chemical’s ability to clean the water to ensure the operating cost reduces the OPEX FranciscoQueralt,HeadOfFacilities&Construction, AmericasPetrogas 3.50 Question & Answer Session POLYMER INJECTION 4.00 Identifying The Optimal Polymer Injection Technique To Improve Aerial Sweep Efficiency And Prevent Water Diversion • Evaluating well surveillance data to determine if polymers can successfully increase the sweep efficiency within a waterflood project • Matching the polymer to the reservoir pressure, temperature and fluid movement to: • Ensure the treatment will have the desired transit and activation time within the reservoir • Prevent cooking through overheating the polymer • Avoid a change in polymer elasticity due to high gas content • Designing the polymer injection rate to improve the EOR of the well CarlosBerto,HeadOfOperations,Tecpetrol 4.30 Question & Answer Session MONITORING & CHEMICAL TRACERS 4.40 Analyzing The Monitoring Benefits Of Chemical Tracers In Evaluating The Success Of The Waterflood Operation And Improve Future Injection • Utilizing tracers to compare the predicted and actual vertical and aerial sweep efficiency of the waterflood to determine if production increases can be attributable to the EOR • Assessing how monitoring injection through the SCADA system can identify well failures to improve the run life of the well • How an operator utilized water tracer results to lower the water cut by identifying the high water content layer and avoiding injection • Outlining how water tracer data has improved injection through defining the optimal reservoir injection pressure to increase production recovery • Assessing if using chemical tracer data can ensure only specific reservoir layers are flooded to maximize well production 5.10 Question & Answer Session 5.20 Chair’s Closing Remarks EARLY LOCAL RATE Register By Friday May 30 SAVE $2700ARS www.mature-fields-argentina-2014.com (1) 800 721 3915 customerservices@lbcg.com
  • 5. I would like to register the delegate(s) below for the 2 day congress Mature Fields Argentina Production Optimization 2014 PYes Telephone Address For Invoice Purposes Zip/Postal Code Country Payment must be received in full prior to the event. * Option 1. CREDIT CARD Please charge my *VISA *AMERICAN EXPRESS *MASTERCARD Expiry date Security Code / CVV (required) Signature of card holder Amount £ GBP Card number Name on card Details PLEASE USE CAPITALS - PHOTOCOPY FOR MULTIPLE DELEGATES Delegate Rates GUESTS ARE RESPONSIBLE FOR THEIR OWN TRAVEL AND ACCOMMODATION ARRANGEMENTS Payment PLEASE TICK APPROPRIATE BOXES AND COMPLETE DETAILS How To Finalize Your Registration * Option 2. INVOICE An invoice containing payment instructions will be sent electronically upon receipt of the completed registration form. Delegate 1 *Mr *Dr *Miss *Ms *Mrs *Other: Name Position Organization Email Delegate 2 *Mr *Dr *Miss *Ms *Mrs *Other: Name Position Organization Email *SAVE 20% ON GROUP DISCOUNTS You can involve your whole organization or team Contact: (1) 800 721 3915 Early Local Rate Standard Local Rate Book And Pay By Friday May 30, 2014 From June 1, 2014 2 Day Congress Pass * $8,900 ARS SAVING $2,700 * $11,600 ARS Audio & Video Recordings * $4,000 ARS Now that your details are completed please send your registration form to our Customer Service Team using one of the following options: Option 1. Email: customerservices@lbcg.com Option 2. Fax: (1) 800 721 3915 Enquiries And More Information Should you have any enquiries or if you would like to request more information contact our friendly Customer Service Team on (1) 800 721 3915 or visit the congress website at: www.mature-fields-argentina-2014.com Terms & Conditions Apply. Please See Our Website For More Information www.mature-fields-argentina-2014.com (1) 800 721 3915 customerservices@lbcg.com

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