2005 Gas-Lift Workshopalrdc.org/workshops/2005_Spring2005GasLift/schedules/… · Web...

2005 Gas-Lift WorkshopTechnical Presentations

Session: New Gas-Lift Technology

Session Chair: Jose Roberto Fagundes Netto, Petrobras

Presentation Title: Petrobras Deep Water Gas Lift Project (an Overview)

Company(ies):Petrobras

Author(s): Guilherme Peixoto Paulo José Pinto RibeiroAlcino Resende de AlmeidaJose Eduardo Mendonça da Silva

Contact Information:

Abstract:The Petrobras Deepwater Gas Lift Project is part of the PROCAP 3000 program and intends to face the challenges of gas lifting in high pressure and high flow rate deepwater wells. The main objective is to search for products that will optimize the gas lift process.

The work is focused in four areas of interest: study of scenarios, equipment development, software development, and gas lift automation. Phase 1 of the project is almost completed and Phase 2 will start soon.

The developed products, accomplished tests, and obtained results for Phase 1 of the project will be presented here, along with a summary.Notes:

Session: Session Chair:

Spring 2005 Gas-Lift Workshop


New Gas-Lift Technology Jose Roberto Fagundes Netto, Petrobras

Presentation Title: The Bubble Breaker

Company(ies):Shell International EP

Author(s): Erik SchramaRichard Fernandes


Abstract:The bubble breaker is an orifice plate that can be installed in a gas lifted or naturally producing well with associated gas to enhance production. By generating intense liquid turbulence the bubble breaker breaks up large bubbles and gas slugs into bubbles smaller than 1 mm. The small bubbles move slower through the liquid and are distributed more homogeneously over the cross section of the production tubing. As a result the small bubbles reduce the hydrostatic head in the well. To generate the turbulence and the small bubbles only a small pressure loss over the bubble breaker is required. If the well is deep enough and the gas-to-liquid ratio is within certain boundaries this results in a net reduction in flowing bottom hole pressure and an increase in production.

The bubble breaker project started as a co-called Game Changer project. At Shell EP Technology in Rijswijk, The Netherlands, different bubble breakers were tested in an 18-meter high, 72 mm diameter Perspex test facility. The proof-of-concept experiments showed that it is indeed possible to break up bubbles and that they can reduce the hydrostatic head significantly.

A field trial in Central Africa showed that the bubble breaker works. A production increase of some 10% could be seen and the flowing gradient survey showed a change in gradient.Notes:





Presentation Title: Real Time Expert Systems For Production Optimization


Author(s): Edson Henrique BolonhiniJosé Francisco CorreaSthener R. V. Campos


Abstract:Expert systems focused on production optimization in Petrobras result from the combination of the petroleum engineer’s knowledge with automation techniques. In order to enhance intermittent and continuous gas lift efficiency and to adapt the system to the operational reality, different control methodologies have been developed.

This presentation will describe strategies based on pattern recognition and a close loop algorithm approach that are helping the production engineers to minimize oil losses, act remotely in distant wells, provide faster diagnostics, and gather historical trends to feedback petroleum knowledge at office desktop. Field cases from each technique will be presented, showing information from the supervisory and the data base architecture that is supporting these strategies.

With this, the management of artificial lift methods has received an important partner from the control and automation engineering area. On the other hand, human resources training and the adaptation to actual installed instrumentation are some of the great challenges of this new field development tool.Notes:





Presentation Title: Fiber Optic Temperature Systems

Company(ies):Schlumberger

Author(s): Vinicius CarvalhoTommy White


Abstract:Distributed Temperature Sensing (DTS) technology has been successfully utilized in several artificial lifted wells to monitor and optimize their gas-lift systems. DTS data has been acquired using fiber optic slickline, which has proven to be a cost-effective solution to diagnose and optimize gas-lift systems, detect completion integrity issues and monitor reservoir inflow distribution.

Through the observation of Joule-Thompson cooling signatures, the DTS monitoring provided real-time visualization of the entire gas-lift system in real time and multiple valve activity, as well as tubing leaks, which allowed immediate problem identification and rectification.

An additional benefit from utilizing the slickline with fiber optics is the ability to monitor simultaneously the gas-lift system and the reservoir. Thermal analysis of DTS data revealed important inflow distribution information while measuring GLS functionality.

The DTS measurement has proven to be a superior tool for optimization of a Gas Lift system to the previously single point pressure measurement or gradient stops. Several case studies will be reviewed were optimization has been applied in real wells.Notes:





Presentation Title: A High-Reliability Gas-Lift Orifice


Author(s): Jim Hall


Abstract:As the industry moves to deepwater and subsea production, intervention costs increase significantly. Front end designs must consider artificial lift depletion plans to minimise life cycle costs. Higher lift gas supply pressures and more stringent regulatory agency requirements combine with the risks associated with floating structures to elevate the importance of wellbore integrity. Gas-Lift practices and hardware that have been acceptable for onshore and continental shelf operations become less financially appealing due to the high cost and risk of wellbore entries to service in-well gas lift hardware.

It is only recently that the industry has produced a step-change in the performance and reliability of the equipment planned for use in high intervention-cost wells. Designed operating pressures are increasing and well integrity issues are being addressed in hardware design. While onshore and shelf operations may accept the leak rates permitted in API Specification 11V1 (and soon ISO 17078.2), deepwater and subsea operations find as-built leaks unacceptable.

The High Reliability gas-lift Orifice (HrglO) was conceived to address a $1MM hard cost associated with a tubing leak tracked down to a $2000 leaking reverse flow valve in a gas lift orifice. A short brainstorming session produced several approaches which were then reviewed and ranked according to development time, cost and compatibility with existing hardware. A patent search produced a similar design to one of the concepts, but the maintenance payments on the patent had been stopped and so the intellectual property was in the public domain.

The concept of a flapper valve addressed the desire for a gas-lift orifice that removed the sealing surfaces of the check valve from the path of high velocity gas and liquids, the primary flaw in the design of traditionally used equipment.

The new design achieves the primary goals of isolating the check valve sealing surfaces, delivering a non-convoluted flow path and compatibility with existing equipment. Leak, flow and erosion testing has been conducted and field testing is planned for 1st half 2005.Notes:





Presentation Title: Turbo Gas Lift-Innovative Hybrid Artificial Lift System

Company(ies):INA, JSC, and TGL

Author(s): Kresimir Kegleviae


Abstract:The operative costs of using ordinary continuous gas significantly rises as oil is lifted from greater depth. The reason is that higher and higher amounts must be compressed on bigger and bigger pressures, as depth rises. Furthermore, maximal intake gas pressure and maximal available amount of gas per well defined by surface gas lift equipment defines maximal possible lifting depth. Consequently, if fluid level into well falls below level of maximal possible lifting depth (defined by gas intake pressure and gas amount), then arises need for surface gas lift equipment redesign, or even introduce of other artificial lift type. The both situations commonly involves huge capital expenditure, which can be avoided by introducing turbo lift system on already using gas lift wells.

Furthermore, use of turbo lift causes huge energy savings compared with ordinary continuous gas lift, especially when static pressure decreases and situation of pressure surplus in gas lift system occurs.

Turbo gas lift method is based on combination of mechanical lifting by pump, and lifting by compressed gas (gas-lift). Pump in turbo lift system is powered by gas turbine fed by same compressed gas, which is after gives turbine power, is used for gas lift. By using compressed gas in such way, gas is doing two works instead of one, which leads to higher energetic efficiency compared with classic gas lift, especially in lifting from big depths.

The turbo gas lift system is combined with further main parts: gas turbine, fed by compressed gas from surface the pump for mechanic lifting of fluid up to above gaslift valve. Pump is powered by gas turbine. standard gas lift equipment which cotains working gas lift valve and release gas lift valves

Key benefits of turbo gas lift: increased volumetric efficiency-higher liquid volumes superior reservoir drawdown-increased production rate production stability-production of only desired fluid amount decreased gas injection requirements lower energy consumption prolonged continious gas lift decreased abandonment pressure

This presentation will show technology fundamentals, recent developments, and results of laboratory tests prior to field trial.Notes:

Session: Keynote Address

Session Chair: José Eduardo Mendonça



Presentation Title: No title submitted


Author(s): Carlos Tadeu Fraga


Abstract:No abstract submitted.Notes:

Session: Gas-Lift Software

Session Chair: Jim Hall, Shell International EP



Presentation Title: A Study of Flow Stability in Gas-Lift Wells Producing from Saturated Reservoirs

Company(ies):University of Mexico

Author(s): Y. V. Fairuzov, SPEI. Guerrero-Sarabia


Abstract:Continuous flow gas-lift wells are susceptible to hydrodynamic instability (heading), which may cause cyclic variations of the wellhead pressure, and oil and gas flow rates. Gas-lift instability is a reason of many operational problems, for example, compressor shutdowns caused by pressure and liquid flow rate surges, difficulties in the operation of low pressure separators, and excessive gas consumption.

Stability problems in complex multiphase systems can be solved using stability maps. A stability map is a plane (2D) diagram that shows the regions of stable and unstable operation of the system, as well as its operating limits.

A study was performed to investigate flow stability in gas-lift wells producing from saturated reservoirs. Different sta-bility criteria proposed in the literature were compared using a gas-lift stability map. Based on this study, recommen-dations on the selection of gas-lift stability criteria were developed. Several examples of gas-lift stability map applica-tions are given. It was shown that stability maps enable designers and operators to determine rapidly the effect of gas-lift design parameters and operating conditions on the system stability. Gas-lift stability maps can also be used for training and educational purposes. Notes:





Presentation Title: Lagrangian Transient Two-Phase Flow Simulator for Gas-Lift


Author(s): Kwon Il ChoiIbere Nascentes Alves


Abstract:The Lagrangian transient two-phase flow model, based on a moving numerical grid, presents the important capability of tracking the gas and liquid’s kinematics precisely, and it’s not subject to numerical diffusion, which is the main drawback of the Eulerian models. At every time step, two moving grids, one for liquid and one for gas, are forzen and superimposed to make material and momentum balances possible. The finite difference cells become elastic, for their sizes vary all the time. The software developed from this new model has to deal with intensive search algorithms, interpolating methods and dynamic memory management.

Applying the Lagrangian model to simulate transient phenomena in Gas-Lift has proved very successful for studying unloading, instability, optimization and even effective gas-lift valve spacing. Other field operations that have been simulated include shut-in and start over. On the other hand, for showing its realistic and dynamic gas fraction distribu-tion, the simulator has been used also as a good visual gas-lift training program. The presentation of this work in-cludes some sample live simulations addressing main issues relating to Gas-Lift. Notes:





Presentation Title: Dynamic Simulation

Company(ies):ScandPower

Author(s): Juan Carlos Mantecon


Abstract:Dynamic Simulation provides an improved process to optimize completion designs in complex wells (subsea, deep subsea, multilateral, multi-layer and smart wells). Dynamic Simulation is also essential to identify and understand the key flow assurance issues during the well’s life cycle. Improving the design and operation (field life cycle) of full production systems (from reservoir to process facilities) to obtain optimum production and minimize investment and operating cost is a very attractive exercise to maximize profit.

This presentation discusses the best current approach for implementing dynamic simulation and establishes its potential for evolving as the sole smart design/optimisation process for complex well completions and production systems to increase oil and gas production and optimise wells, pipelines, and facilities design. In the particular case of gas lift systems, Dynamic Simulation is also fundamental for optimising the well’s unloading process (transient). Dynamic simulation of production systems at early stage is essential to identify and understand the key flow assurance issues. It allows better project definition during the concept selection, FEED and detailed design phases. Dynamic simulation of operative production systems should minimize workover intervention and wireline activities, maximize safety, as well as enable operators to optimize, accelerate, and increase the recovery through the life of the well/field. Additional benefits are obtained from real-time surveillance - faster detection and diagnosis of problems, and quicker response to failures.Notes:

Session: Gas-Lift Standards

Session Chair: John Martinez, Production Associates



Presentation Title: API Gas-Lift Recommended Practices

Company(ies):Oilfield Automation ConsultingProduction Associates

Author(s): Cleon DunhamJohn Martinez


Abstract:Gas-lift is major form of artificial lift. Many companies use it to produce large quantities of oil. It is being used more and more to assist in production of gas wells.

Starting in 1979, a group of people from the gas-lift industry came together under the auspices of the American Petroleum Institute (API) to develop specifications and recommended practices for gas-lift. To date, one specification and five recommended practices have been developed and two new ones are underway. These are:

Existing documents– API Specification 11V1 – Gas lift valves, orifices, dummies– API Recommended Practice (RP) 11V2 – Gas lift valve testing, modeling– API RP 11V5 – Gas lift operations (revision in progress)– API RP 11V6 – Gas lift design– API RP 11V7 – Gas lift valve reconditioning– API RP 11V8 – Gas lift systems

Documents under development– API RP 11V9 – Dual gas lift − API RP 11V10 – Intermittent gas lift This presentation will highlight the purpose of each of these documents and how they can be obtained and used to facilitate training and best practices in oil and gas production companies.Notes:

Session: Gas-Lift Standards

Session Chair: John Martinez, Production Associates

Presentation Title: Company(ies):



ISO Gas-Lift Standards Oilfield Automation Consulting

Author(s): Cleon Dunham


Abstract:The International Organization for Standards (ISO) is producing gas-lift standards for the gas-lift industry. Currently, four standards are being developed:

ISO 17078.1 – Side-pocket mandrels. Published by ISO in Dec. 2004.

ISO 17078.2 – Flow control devices for side-pocket mandrels. First draft completed; starting international review process.

ISO 17078.3 – Running, pulling, and kick-over tools, and latches for side-pocket mandrels. Being drafted.

ISO 17078.4 – Practices for side-pocket mandrels and related equipment. Being drafted.

The existence of these standards will:

Permit the user/purchaser to specify the equipment quality that is required for each specific application.

Be assured that each piece of equipment is manufactured and tested according to specific requirements.

Assure that new equipment suppliers who claim to meet these standards are required to demonstrate compliance with these standards.

This presentation will highlight the standards and the unique testing requirements that are associated with each device.Notes:

Session: Breakout Sessions

Session Chair: Cleon Dunham, Oilfield Automation Consulting

Breakout Session: Gas-Lift in Sub-Sea Wells




Session Coordinator(s): Jose Mendonca


Notes:



Breakout Session: Gas-Lift Automation

Company(ies):Oilfield Automation Consulting



Session Coordinator(s): Cleon Dunham


Notes:



Breakout Session: Simulation of Well Start-Up

Company(ies):PPCLScandPower



Session Coordinator(s): Fortune BikoroJuan Carlos Mantecon


Notes:

Session: Gas-Lift Field Reviews

Session Chair: G. Peixoto, Petrobras

Presentation Title: Pack Off Gas-Lift Installations Enhance Production in an Older Field

Company(ies):Weatherford

Author(s): Contact Information:



Ken Hilse

Abstract:Changing well environment during the life of a well has a great impact on the wells producing capability. In artificial lift installations these changes can render the original design obsolete. In the gas lift method of artificial lift, there are many methods to apply the application. One method consists of installing pack off gas lift stations in a well by using standard wireline equipment, tools and procedures. The configuration consists of a gas lift valve installed between upper and lower sealing elements. Pack off equipment can be installed in a well to isolate holes in the tubing, introduce gas lift equipment in wells that are not currently completed with gas lift valves and to add additional gas lift stations to installations where the gas lift design is no longer sufficient to produce the well in an optimum manner. The pack off sealing elements isolate an area of the tubing that has communication established either be a sliding sleeve or a previously perforated hole allowing injection gas into the valve area when used as a gas lift application.

A field off the coast of Eastern Malaysia was losing gas lift efficiency due to pressure depletion, increasing water cuts and faulty equipment. The current gas lift designs were not valved deep enough to maintain rates and in some instances, wells had been shut in for years. The operator’s engineering staff determined the most economical method of returning the affected wells to production and in doing so, realized some sizeable gains in net production from wells that had not been on production for some time.

This presentation will discuss the equipment applied, installation procedures and actual results of pack off gas lift applications in the Malaysian gas lift field.Notes:



Presentation Title: Unlocking the Value of Marginal Assets:“Production Optimization through Effective Integrated Production System Modeling”

Company(ies):Petroleum Consulting Ltd.

Author(s): Fortune Bikoro




Abstract:Marginal fields are one of the word’s growing sources of oil, specially in mature oil producing regions where the production is declining, and the way to stem that decline appears to be in extracting new oil from smaller new fields.

Integrated production system modeling can be defined as the measure of operational health that provides an effective understanding of actual wells and field production performance.

Considerable savings can be made in terms of time using the integrated production system modeling concept to cycle through the entire production network, and predict the effects of changes through a systematic analysis of reservoir response, wells and flowlines behavior and the impact of their interaction on field performance so crucial in marginal assets.

The presentation covers the approach taken to the problem of production optimisation in these marginal fields by using nodal analysis and network modelling as a cost-effective way to increase production.

The presentation shows how this approach has provided effective understanding enabling production increase, and OPEX risk based investment decisions. Notes:



Presentation Title: Gas-Lift Valve Temperature Distribution: Theoretical and Experimental Analysis

Company(ies):State University of Campinas

Author(s): Marcelo M. GanzarolliCarlos Alberto C. Altemani




Alcino Resende Almeida

Abstract:Retrievable gas-lift valves (GLV) like the Camco R-20 have a nitrogen-charged dome acting on the GLV bellows. This pressure is counterbalanced by the injection gas pressure to control the GLV operation. The nitrogen temperature affects the pressure and depends on both the well fluid and the injection gas temperatures. The purpose of this work was to investigate this dependence for a GLV in a side pocket mandrel.

Initially a compact thermal model was developed to estimate the thermal resistances from the dome to the other parts of the GLV. The results of this investigation indicated that the axial resistance along the GLV body was much larger than the radial resistance from the dome to the mandrel tube. This model was based on heat transfer correlations and approximations, and its conclusions needed verification by experiments.

A Camco R-20 GLV was assembled with 5 mm clearance in a steel tube and both were placed against the inner surface of a 150 mm inside diameter vertical Plexiglas tube. Hot water was forced through the Plexiglas tube and either compressed air or ambient water was forced through the GLV. The experimental results corroborated the compact model predictions.

The GLV dome temperature would thus be determined essentially by the radial and circumferential conduction around the mandrel tube. This is influenced by the convective heat transfer with the well fluid at the inner surface and with the injection gas at the outer surface. A numerical thermal model was then used to evaluate the mandrel tube temperature distribution and its average value at the surface around the GLV. From the numerical results, it was possible to obtain an approximate correlation for the nitrogen temperature at the GLV dome as a function of the injection gas and the well fluid temperatures.Notes:



Presentation Title: Benefits of Detailed Compressor Modeling in Optimizing Production from Gas-Lifted Fields

Company(ies):eProduction Solutions / Edinburgh Petroleum Services

Author(s): Manickam S. Nadar – AuthorGreg Stephenson - Presenter




Abstract:Compression management plays an important, but often overlooked role in the optimization of gas lift networks. This paper describes the role of compressors in gas lift systems and explains why it is important to accurately account for compressor performance in full field networks.

Software tools are now available to assist the engineers in the modelling and simulation of complex fields with non-hierarchical production and injection networks. These tools are capable of solving the total system network and suggesting optimum values for critical parameters such as gas lift injection rates and pressures, and production system pressures.

Recent optimization studies of complex gas lifted fields have indicated that modelling of gas lift compressors as a part of the field network can uncover opportunities that add significant value in the operation of the field. To illustrate the benefits of rigorous compression modeling, the author presents a case history from the Middle East, including results and key lessons learned. The case study has indicated that the optimization of the field networks, after incorporating detailed compressor models, gives the following benefits: It allows the operator to operate the field closer to the optimum under changing production conditions. It allows the operator to model the changes in gas turbine performance due to changes in ambient conditions, so

as to make the best use of the power available at all times. It allows the operator to examine the horsepower required for optimum gas lift operation of the entire field

network. When the available compression horsepower is less than what is required, the economics of adding additional

horsepower can be examined. Conversely, when the available compression horsepower exceeds the optimum required, actions can be initiated to avoid wastage of power.

When the gas lift compressors are driven by gas turbines, it allows the operator to monitor the fuel gas consumption.

This presentation will include a discussion of simple vs. complex compressor models, along with the implementation and calibration of compression models. Notes:



Presentation Title: A Day in the Life of a Gas-Lift Well Analyst

Company(ies):AppSmiths

Author(s): Dwayne VetterDan DeesLarry Peacock


Abstract:



Provided with the latest technology, tools, and training, the Gas-Lift Well Analyst can increase his/her performance and benefit to an organization. The analyst is one of the key links in the day-to-day operation of a Gas-Lift field and proper emphasis should be placed on the position in any company that strives to get the most out of what they have. If this vital position is ignored, the best intentions of any well managed Gas-Lift field will not be as successful as they should be given just a little focus to the staffing needs, tools and training required in this key role.

Once the position of a Gas-Lift Well Analyst has been established, some key basic guidelines for the role and what it should be responsible for are needed to ensure it is clear what the day to day activities for this staff position are and how they fit into the overall organization.Notes:



Presentation Title: Remote Workforce Solutions from a Global Gas Lift Help Desk

Company(ies):Schlumberger

Author(s): Tommy White


Abstract:By fully exploiting the data and information at their disposal, E&P companies can increase efficiency, improve financial performance, maximize asset value and strengthen competitive position in a dynamic marketplace. Success depends on



transforming data and information into verified, instantly accessible knowledge as a basis for real-time decision-making. This is achieved only by creating a structure around knowledge capture and sharing. This paper will review the successful implementation of gas lift knowledge solutions from a global help desk perspective and show how a virtual knowledge base can add value by enabling a remote workforce access to procedures, techniques and proven practices.Notes:

Session: Low Rate Gas-Lift

Session Chair: Nereu, Petrobras

Presentation Title: Maximizing Net Present Value in Mature Gas Lift Fields

Company(ies):Halliburton, ESG

Author(s): Oscar MoraRichard A. StartzmanLuigi SaputelliLidiana M. N. RibeiroJoão Otávio L. Nunes




Abstract:Advances in mathematical modeling and real-time monitoring have made it possible to more realistically and accurately simulate and measure the future physical behavior and economic performance of gas lifted oilfields. Mature fields, with installed gas lift facilities (e.g. compressors, flowlines, downhole valves) and reliably calibrated reservoir and facility flow models present a favorable opportunity to apply improved and more general optimization methods.

This paper describes a new approach for optimizing gas lift operations in mature oilfields.

The new approach maximizes Net Present Value by integrating mathematical models that describes the behavior of the reservoir, the behavior of the fluid gathering and gas lift systems, and the future economic performance of the field operating under gas lift. This integrated approach is in contrast to those in current use that typically seek to either maximize current oil production rate or to maximize the gas lift efficiency of individual wells.

We used a case study for a hypothetical field to demonstrate our approach. Our results showed that the optimal oper-ating conditions that maximize Net Present Value do not necessarily occur at either the maximum production rate or at the maximum gas lift efficiency.Notes:



Presentation Title: Intermittent Gas-Lift

Company(ies):Production Associates

Author(s): John Martinez


Abstract:Intermittent gas lift is a good application in low reservoir pressure wells that benefit from batch or slug production. The reservoir pressure or productivity has declined and the attainable flowing bottom hole pressure cannot effectively lift the continuous flow column of fluid.



The batch production technique allows the gas slug to lift a liquid slug, yet the column is mostly gas after the slug surfaces, which causes bottom hole pressure to be low and permits the reservoir to feed another small slug into the wellbore.

Data from testing will give the characteristics of the intermittent gas lift batch process. Application guidelines will be given for appropriate usage of intermittent lift.Notes:



Presentation Title: Shell Experience with Plunger Assisted Intermittent Gas-Lift (PAIL)


Author(s): Charlie Moncur – AuthorJim Hall - Presenter


Abstract:Intermittent gaslift has not found much favour as an artificial lift technique in Shell Operating Companies. Shell has



trialed and tested intermittent gaslift installations since 1962 in a number of its operating units. Success with intermittent lift has been limited due to the poor capabilities of the surface control units, hardware and the additional operational workload, which these systems generated. Intermittent gaslift was seen as an art rather than a science and placed in the “too difficult box”.

A specific intermittent lift technique PAIL (Plunger Assist Intermittent Lift) was developed and used in a Shell operating company over the last 2 decades. A total of 10 wells have been produced on PAIL with varying degrees of success. Despite the poor performance a number of wells have remained in production, for some 14 years, with PAIL systems. These wells have produced significant cumulative volumes of oil.

The latest trial with Parkburn Well Management Systems Ltd. control units has proved very encouraging. The control system was retrofitted to two existing PAIL installations. These control units proved significantly superior to those previously installed. The viability of PAIL as an artificial lift technique has significantly improved.

Production increases and reduction in gaslift was achieved on both wells. The control unit catered for automatic kick-off of the well, production logging and automatic optimisation of the well cycle to deliver maximum production at optimum cycle frequency. The control unit developed can also orchestrate multiple wells and prevent synchronisation of the production cycles. Bean back to a lower rate is also possible with automatic adjustment of slug size and gaslift injection requirement per cycle. As reservoir pressure and well productivity decline, continuous gaslifted wells can be converted to beam pumps. The conversion and subsequent maintenance of these wells can be expensive in terms of life cycle cost. There is an argument to support continuing production under a gaslift regime (PAIL). With application of PWMS Ltd. systems a viable alternative to beam pumping is available. Production range is from a few barrels per day up to the level where continuous gaslift is viable is possible. Notes:

Exhibits

Notes:

2005 Gas-Lift Workshopalrdc.org/workshops/2005_Spring2005GasLift/schedules/… · Web...

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