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2016 Gas-Lift WorkshopTechnical Presentations

Session: I Sub-Sea, Horizontal Wells

Session Chairs: Greg Stephenson, Bongo (aka Jim Hall)

Presentation Title: I – 1 NexLift

Company(ies): Petroleum Technology Company (PTC)

Author(s): Vennlig Hilsen

Contact Information: [email protected]

Abstract:Challenge. Conventional side pocket mandrels (SPM) have inherent challenges related to welding and heat-treatment. These issues are exacerbated when welding nickel-chromium alloys, such as S13%Cr, 25%Cr and Alloy 718, common materials for high cost completions. Challenges caused by manufacturing processes such as welding and post weld heat treatment require stringent and elaborate QA/QC processes.

Solution. Today, SPMs are the only welded loadbearing component in a modern completion string. The elimination of welding brings the SPM to the same structural integrity level as the rest of the machined components in the string. Petroleum Technology Company's (PTC) NexLift(tm) SPM enhances the robustness of the completion string and is the best choice for challenging well applications in which superior strength and enhanced pressure capabilities are required. The API 19G1 qualification assures full compatibility with the gas lift equipment designed and manufactured to API standards.Notes:


2016 Gas-Lift WorkshopTechnical PresentationsSession: I Sub-Sea, Horizontal Wells


Presentation Title: I – 2Old Ideas Become New Again – A New Approach to the Differential Valve

Weatherford Artificial Lift

Author(s): Steve Long


Abstract:The purpose of this presentation is to explain a new type of differential gas lift valve that will operate with varying injection pressures. Most gas lift valves being used today are injection pressure operated (IPO) gas lift valves, which require a predetermined constant supply of injection gas pressure to operate properly. An operator is faced with the decision of setting the pressure of the valves based on the minimum injection pressure available at all times. Since the depth of injection, and thus the production rate in many cases, is dependent on the injection pressure available, a well operator may be losing out on opportunities to produce a well at a higher production rate when higher injection pressures are available in the field.

Differential valves were some of the first gas lift valves used in gas lift applications. Their simplicity in design and ability to produce a well with varying injection pressure was one of the advantages of using these valves. Some disadvantages of the original differential valve designs were that these valves were somewhat unpredictable and required special attention from field operators to operate properly. Further, higher quantities of differential valves were needed in a completion utilizing differential valves, compared to IPO valves. Although differential valves were used frequently in the early years of gas lift, the IPO valve became the most popular gas lift valve used because of its operational characteristics and advantages over the differential valve. However, as previously stated, the IPO valve pressure settings have to be based on a predetermined constant supply of injection pressure available at all times to operate properly.

Recent needs in the oil and gas industry involving extremely high injection pressures and situations in which the injection pressure may vary in a field operation have led to a reinvestigation of the differential valve design. Weatherford has developed and tested a new type of differential valve based on a different mechanical design that has addressed the disadvantages related to problems with the old differential valve design. By using similar design concepts from a velocity closed type subsurface safety valve, some of the inherent limitations of the old differential valve have been overcome. Weatherford’s new differential valve has been flow tested with positive results to warrant use in the gas lift industry in situations in which the injection pressure may vary in a specific field operation.Notes:




Presentation Title: I – 3Reducing Intervention Time/Cost During Completion

Company(ies): Petroleum Technology Company (PTC)

Author(s): Vennlig Hilsen


Abstract:Challenge. When completing new gas lift wells the standard practice is often to install dummy valves in all side pocket mandrels. These dummy valves provide a barrier between the annulus and the tubing during the well completion phase. Before the wells can start producing, the dummy valves need to be replaced with gas lift valves. These intervention operations are often time consuming and costly.

Solution. Petroleum Technology Company's ShearLift-T valve has a unique design, which utilizes the barrier technology from the standard SafeLift. The ShearLift-T valve provides a barrier between the tubing and annulus when installed in a side pocket mandrel. The check valve is held in the closed position by a shear device located in the nose section of the valve. Increasing the tubing to annulus differential pressure, to a predetermined level, shears open all ShearLift-T (IPO & Orifice) valves in the tubing string. This allows communication from annulus to tubing. Costly change out of dummy valves in new completions can be avoided by using ShearLift-T.Notes:




Presentation Title: I – 4High Pressure Gas-Lift: Is Industry Missing a Potentially Huge Application to Horizontal Oil Wells?

Company(ies): Encline

Author(s): Bill Elmer


Abstract:The concept of High Pressure Gas-Lift, as written about by Dickens in SPE 14347, has tremendous potential to replace submersible lift as the initial form of artificial lift in horizontal oil wells. Conventional gas lift, long recognized as an excellent method for producing high volumes of solids- laden fluid from deviated wells, underperforms in new horizontal oil wells compared to submersible lift. This is not because gas-lift cannot do the job, but rather that industry has virtually ignored the practice of High Pressure Gas-Lift. Similar to a coil tubing cleanout using high pressure nitrogen, high pressure natural gas can lift large volumes of fluid without the need for gas-lift valves, or with only one gas-lift valve.

The technology and products to do this currently exist. Gas-lift valves rated for 5000 psi operation are available, and compressor cylinders (created relatively recently for CNG application) are also available. Instead of operating a conventional 3 stage wellhead compressor moving gas from 45 psig to 1000 psig, only one additional stage is required to move gas from 45 psig to 4000 psig, as well as only 30% more horsepower. Compressor performance runs to substantiate the application will be presented.

Finally, possible reasons that have caused High Pressure Gas-Lift to be ignored will be proffered, so that they can be mitigated by industry, in order to encourage the acceptance of High Pressure Gas-Lift as an improvement to horizontal oil well operation. Notes:




Presentation Title: I – 5A Day in the Life of a Gas-Lift Well Analyst

Company(ies): AppSmiths

Author(s): Larry Peacock


Abstract:Provided with the latest technology, tools, and training, the Gas-Lift Well Analyst can increase their performance and benefit to an organization. The analyst is one of the key links in the day to day operations 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:


2016 Gas-Lift WorkshopTechnical PresentationsSession: 2 New Gas-Lift Technology, Design, Automation

Session Chairs: Eric Lovie, Mike Johnson

Presentation Title: 2 – 1Fiber Optic Based Gas Lift Surveillance

Company(ies): Shell Global Solution International B.V.

Author(s): Gijs HeminkMurat Kerem


Abstract:Gas lift surveillance is one of the areas where fiber optic based Distributed Temperature Sensing (DTS) and Distributed Acoustic Sensing (DAS) may provide value by identifying actual lifting port and/or multi-porting gas lift valves.

Interpreting DTS data acquired in gas lifted oil wells equipped with a clamped fiber optic cable requires understanding of the (subtle) temperature variations that occur due to lift gas injection to correctly assess the status of the valve (lifting, shut, leaking).

A detailed hydraulic and thermal analysis of such a well has been conducted using a transient multiphase flow simulator in order to predict the temperature response of different multi-porting scenarios. The outcome of the modeling work shows that:

The calculated temperatures for the simulated actual well test are in a very good agreement with the corresponding DTS traces coming from the well. The actual lifting port (orifice valve) is clearly visible in both.

The calculated multi-porting responses however are different from the temperature variations observed in the DTS traces.

The simulation results enhanced our current understanding of the thermal behavior in gas lifted oil producers as they showed that the temperature response of multi-porting can be visible on DTS data, but in a different way from what has previously been expected.

A DAS survey was conducted in the several oil producers where DAS measures the acoustic signature created by the injection of lift gas through a port. The interpretation shows that DAS indicates where lift gas is injected (the unloading or orifice valve) and that DAS responses to gas lift injection rates change. Furthermore, the DTS and DAS interpretation are in agreement, e.g. they indicate injection of lift gas through the same lifting port.Notes:




Presentation Title: 2 – 2Wireless Technologies for Gas Lift Surveillance

Company(ies): ExxonMobil

Author(s): Michael Romer


Abstract:Wireless sensing devices were installed on an offshore asset to enhance data collection for gas lift surveillance. The successful “permanent” wireless equipment installation led to development of a portable “wireless suitcase”. This presentation will describe the technologies employed, the field trials of the permanent and portable systems, and will discuss how the additional data sources can improve gas-lift optimization activities.Notes:




Presentation Title: 2 – 3New Approach to Full Field Gas Lift Optimization

Company(ies): PSE Oil and Gas

Author(s): Kevin Wade


Abstract:The low oil price clearly provides the industry with some challenges and the need to optimize oil production is now more prevalent than ever. A number of software tools already exist on the market that already perform field wide gas lift optimization where the gas lift is a scarce quantity.

However, while these tools clearly improve the oil production by the re-allocation of the lift gas quantity do they fully optimize the field in terms of oil production? The answer is generally no. For example would oil production be improved if a well was switched from manifold A to B or a pipeline routed through riser X rather than riser Y? Traditional tools can normally only answer these questions by taking the solver and wrapping it inside some outer process that runs through all possible combinations. Even with a relatively small field the number of possible combinations quickly becomes unmanageable to the extent that calculations can take hours or days to complete. Clearly a calculation time of days is unacceptable when the operator is looking to make a quick decision on the operational configuration of a field.

To assist the industry in getting optimal solutions in a timely fashion, PSE has created new optimization technology based on the gPROMS equation based framework. This, not only optimizes the traditional gas lift quantity (and any continuous variable), but can also optimizes discrete decisions like well routing, pipeline routing and well status all within in an acceptable time fame.

Some recent case studies will be presented that highlight the advantages of the PSE approach in terms of improved solution (oil rate or revenue) and speed of solution on a variety of field configurations. As an example a case that involved discrete optimization that took 5½ days to produce an optimal solution with a leading tool takes less than 10 minutes with the new PSE solution. The PSE solution also yields a final solution that improves on the objective function (in this case field revenue) by over $150,000/day.Notes:




Presentation Title: 2 – 4Automating Gas-Lift Injection Rates

Company(ies): Emerson Process Management

Author(s): Sudhir Jain


Abstract:Gas-Lift Optimization is a very well versed technic of artificial lift. It is very common to have resource constraint on platforms and onshore in terms of availability of gas and water disposal capacity.

In this presentation, we will discuss how optimization application allocates resources to get maximum return on investment.Notes:




Presentation Title: 2 – 5Edge-Welded Bellows Technology Including Trade-Offs Between Stroke, Pressure, and Cost and the Differences Between Edge-Welded and Formed Bellows

Company(ies): Senior Metal Bellows Engineering

Author(s): Pat Reed


Abstract:Edge-welded bellows applications for the oil and gas industry will be presented.

Edge-Welded Bellows Technology What is an edge-welded bellows?

Materials of construction Methods of manufacture

Types of edge-welded bellows 3 ripple and other plate shapes HIPRES bellows

Design considerations Stroke Pressure Cost Spring rate Temperature

Differences between edge-welded and formed bellows Stroke Cost

Edge-Welded Bellows Assemblies for Oil and GasMany challenging problems can be solved using higher level assemblies that incorporate an edge-welded bellows. Quite often bellows can be combined in unique ways and coupled with other technologies to create novel, hermetically sealed, all metal solutions to challenging pressure, temperature, leakage and reliability issues. These include automatic thermal actuators, valves, and switches; maintenance-free accumulators and pressure surge dampers; bellows compressors and pumps; and many more.Notes:




Presentation Title: 2 – 6An Overview of Positive Displacement Scroll Technology for Oil and Gas Applications

Company(ies): Air Squared, Inc.

Author(s): Bryce Shaffer, Andrew Morton


Abstract:Positive displacement oil-free scroll technology offers significant advantages over traditional positive displacement compression and expansion devices. The smooth rotary motion of the device lends itself to lower vibration and nose, a compact size and high reliability due to the low part count. Until recently, most specialized applications for oil-free scrolls have been in aerospace due to their low size and weight, medical due to their low vibration and noise, and fuel cells due to their compact size and high reliability. Historically, oil and gas applications have been considered outside the capability of scrolls. The high pressure requirement in some oil and gas applications have been monopolized by reciprocating compressors. Air Squared has successfully built and tested a high pressure oil-free scroll compressor for a natural gas application. Preliminary testing has proved that the pressure capabilities of the scroll can be pushed to accommodate certain oil and gas applications.

The scroll concept was first invented in 1903 by a Frenchman by the name of Leon Crox [1]. The original patent was for a “Rotary Engine”, his goal was to use the device as a positive displacement expander for a steam engine. Unfortunately, the manufacturing tools at the time couldn’t accommodate the high tolerance required for sealing the machine so he was never able to produce a successful prototype. The concept laid dormant for much of the 20th century until the refrigeration industry applied the compressor as a positive displacement compressor for oil-lubricated refrigerant compression for refrigeration applications. Today the scroll device continues to replace traditional positive displacement devices across wide variety of applications.

Scroll devices have a low part count, composed of a fixed and orbiting scroll, three idler shafts a crank, counter weights and bearings. The geometry gives natural valveing which eliminates the need for any inlet/outlet valve structure. The low part count increases reliability for oil free applications and allows continuous duty for up to 15,000 hours before only the tip seals need replacement. In addition, the scroll can be easily hermetically sealed for only static seals through the implementation of a magnetic coupling.

Previous estimates have suggested that oil-free scroll devices maximum differential pressure capability is around 50 psi before significant volumetric efficiency depredation. This assumption has concluded in favor of traditional reciprocating compressor which have a high differential pressure capability but suffer from reliability issues and can’t be easily hermeticised. Air Squared recently completed performance and life testing of a natural gas compressor which can take in high pressure gas over 1600 psia and provide a boost of pressure over 200 psi. In addition, volumetric efficiencies over 80% were observed at 150 psi differential and significant efficiency degradation wasn’t observed until over 200 psi differential. With success of the compressor, Air Squared has opened the door for the oil-free scroll to be applied in a wider range of oil and gas applications from pressure boosters to high pressure natural gas expanders for remote power where reliability is key.

[1] Creux, L., Rotary engine. US Patent No. 801182. 1905.


2016 Gas-Lift WorkshopTechnical PresentationsSession: 3 Gas-Lift Field Case Histories

Session Chairs: Wayne Mabry, Michael Romer

Presentation Title: 3 – 1Pilot Installation of a Deep Gas Lift System to Optimize Gas Lift Well Performance in Brunei Shell Petroleum

Company(ies): Brunei Shell Petroleum

Author(s): Cio Cio MarioJ.W. Hall


Abstract:One of the oldest and largest offshore oil fields in Brunei Shell Petroleum has been on stream since 1972, and uses gas lift as the main artificial lift method. After over 40 years of production, the field reservoir pressure has reduced significantly, which leads to non-optimum gas lift performance. Deepening of the gas lift injection point becomes important in order to optimize the gas lift performance.

Based on an integrated evaluation which consisted on a multidiscipline collaboration between the Well Reservoir and Facility Management (WRFM) and Well Services team members, a Deep Gas Lift (DGL) system method was selected, based on a set of criteria, to be deployed as a pilot for deepening gas injection point of one well.

The existing deepest gas lift mandrel was straddled with two packers and a crossflow assembly that provided dual flow paths in a single system. Additional 350 m of 1.5 inch coiled tubing string was installed as part of the Deep Gas Lift System that acted as the injection string to a predetermined depth. The DGL assembly was successfully installed in a safe manner using coil tubing and a dedicated marine vessel. Well integrity and double barriers regulation were maintained in every step of the DGL installation. After installation of the system, the drawdown increases as per expectation which is 2 times of previous drawdown and the production rate increased significantly.

Based on this 1st successful pilot installation in Brunei Shell Petroleum, BSP plans to install more Deep Gas Lift systems for other non-optimum wells with same approach of selection criteria and method. Notes:

mailto:[email protected]




Presentation Title: 3 – 2Intermittent Gas-Lift Utilizing a Pilot Valve

Company(ies): Flowco Production Solutions

Author(s): Matt Young


Abstract:The field trial is focused on utilizing a pilot valve to obtain low instantaneous FBHP for low rate, low reservoir pressure horizontal wells. The pilot valve system is an alternative use for a positive displacement pump application. The presentation will cover the operation and use of the pilot valve. As well as cover well application and total fluid rate recovery expected while on pilot valve intermittent service. Operational fixes, and improvements will be discussed and shown as a means to improve efficiency and reduce % loss during intermittent cycles.

Production results from pilot valve tests will be indicated along with predicted FBHP to illustrate the change in FBHP and resulting drawdown from low reservoir pressure wells.Notes:




Presentation Title: 3 – 3Batch Foaming Gas-Lifted Oil and Liquid Loaded Gas Wells in BSP

Company(ies): Brunei Shell Petroleum, Shell Oil Company

Author(s): O. OwoyemjJ.W. Hall


Abstract:The East asset in Brunei Shell Petroleum Sdn Bhd operates several hundred producing wells, which are mainly oil producers with a smaller number of gas producers. The majority of the oil wells have been producing for over 20 years wherein reservoir pressure has decreased, water cut has increased, and gas-lift is used for artificial lift. Additionally, some of the high rate gas wells have gradually become liquid loaded and suffer from kick-off issues.

Foam as a de-liquification method has been used within Shell for many years, and its application is being expanded beyond the traditional application in gas wells. The efficiency of the continuous flow gas-lift system is mainly dependent on the degree of injected gas breakthrough and liquid fall back. Here, the suggested mechanism is that, with the addition of foam, gas breakthrough and liquid fallback can be avoided or kept minimal, therefore, improving liquid production. However, very few field trials have been conducted to date in continuous gas-lifted oil wells.

This paper highlights experiences from the first batch foaming trial on gas-lifted oil and liquid-loaded high rate gas wells. Foam injection was carried out in three different well types (partially loaded continuous flow gas-lift well, a well with kick-off issues, and a non-producing well).

The results from foam application were mixed with 50% of the wells responding positively to treatment wherein one candidate showing around 40% increase in liquid production. Challenges as well as future strategy within the East asset are also presented. Notes:




Presentation Title: 3 – 4Foam Assist in a Gas-Lifted Oil Well

Company(ies): Royal Dutch Shell – NAM

Author(s): Ahmed FaragTony RobertsonAnkur MittalKees VeekenTjerk JoustraJacobo Montero


Abstract:Continuous Foam Injection via capillary string is a proven deliquification technology in gas wells with significant water production, but it typically fails in the presence of condensates and oil, and is therefore deemed unfeasible in oil producers. However, for oil wells operating at high water cut, where availability of gas is limited, downhole injection of foam may prove feasible to increase the lifting capacity.

A continuous foam trial was executed in a gas lifted oil well in late 2015. The well was selected due to a combination of poor gas lift design; high water cut, and limited available gas lift pressure and rate. The objective of the trial was twofold: first, to increase the production of the well by injecting foam downhole at the commonly available gas lift rate and pressure. Second, to produce at the common liquid rates at an optimum foam injection rate and lower gas lift. The trial was carefully designed and monitored to prevent a process upset whilst maintaining produced oil and water specifications. The trial results show a trifold increase in gross and net production rate, as well as a 30% reduction of gas lift requirement with downhole foam injection.

The paper describes detailed aspects of the trial, including candidate selection, execution, and technical and economic results. The results can be used as reference for replication of the method in analogue fields and wells.Notes:




Presentation Title: 3 – 5Gas-Lift and Capillary Injection Bring New Life to Bakken Producers with Salt Deposition Problems

Company(ies): Weatherford Artificial Lift

Author(s): Christopher HandRandy Matthews


Abstract:Artificial lift selection in the Bakken shale has been an ongoing process since the beginning of the discovery. In many cases, multiple lift types will be employed during the life of the well. This presentation will cover how gas-lift with capillary has been a success in the window between natural flow and Reciprocating Rod Lift. The optimal gas lift design includes a production packer in the completion. Proper packer placement is important so that maximum drawdown with gas lift is obtained without risking the packer getting stuck when it comes time to remove the system to replace with a positive displacement pump.

The Bakken shale has seen many types of hostile environments. Salt and Paraffin issues can limit production and increase lease operating expenses (LOE). Back side injection was used as a method to try and deliver the proper chemicals to the source of the problem with very little success. The results were shorter run times, higher LOE, and loss of production. Implementing the use of capillary injection strings attached to the outside of the production tubing has helped to improve this situation by providing a means of injecting smaller volumes of chemical and fresh water precisely at the source of the problem without having to deal with high fluid levels or gas interference.

Equipment selection for the Bakken applications is critical due to higher operating costs in the harsh environment. With maintenance costs in mind, some Operators have opted to complete with wireline retrievable equipment. Gas lift applications in the Bakken have seen excellent results and some wells have been produced with gas lift at higher rates than initial natural flow production. Costs associated with rod wear, remedial workover for salt plugs, or sandy well conditions have decreased with gas lift and Capillary systems in place.

Notes:




Presentation Title: 3 – 6Improving the Design of Wellhead Gas-Lift Compressors

Company(ies): Encline

Author(s): Bill Elmer


Abstract:Thirty years ago, it was common for oil and gas operators to own and maintain their compressors. For various reasons, renting this equipment from third parties has become the norm. A common refrain is that returns are better on drilling, so capital allocation for purchasing compressors does not make sense.

As a direct result, the design of the wellhead gas-lift compressor is no longer determined by oil and gas operators, but by compressor rental companies, who have goals that can diverge from the well operators. Further, oil and gas operators have lost in-house knowledge regarding the capabilities and design of compressors. This creates a natural barrier to impede innovations, other than those forced by environmental regulations or cost savings. Unfortunately, the standard rental compressor was developed years before the industry identified tens of thousands of horizontal oil drilling locations.

The author(s) identify several design changes beneficial to horizontal oil wells. The slugging tendencies of horizontal oil wells favor the operation of separation equipment at slightly elevated pressures to easily allow for gas-lift operation to be performed with two-stage compressors instead of three-stage. Although the reasons why this is better are self-evident (less horsepower and one stage less of components), the rental compressor industry prefers to offer standardized three stage compressors, and be able to use them for either gathering or gas-lift applications, which have far different requirements.

Several other operator-friendly design changes will be described in the presentation that can benefit either gaslift or gathering applications. For example, the standard rental compressor package design does not control gas temperatures, and will cool wellhead gas to temperatures that result in condensing substantial volumes of natural gas liquids such as propane and butane. These can precipitate downtime by freezing dump lines, and create environmental liability if vented. By maintaining gas temperatures above 120 degrees, they can stay in the gas phase all the way through the compressor. Also, the benefits of electric driven compressors, and the elimination of the environmentally problematic practice of blowing down prior to restarting, will be discussed.Notes:




Presentation Title: 3 – 7Understanding Gas-Lift Equipment Issues in Deep Water, High Pressure, High Temperature Applications

Company(ies): Shell International

Author(s): Steven Freeman


Abstract:The presentations will address the limitations of current gas-lift equipment in deep water high pressure/ temperature applications and the process to develop fit for purpose equipment

Deep water issueso Well design limitations forced upon GL

Tubing/Casing design issues Available compression

Max injection depth constraintso Single SPMo Multiple SPM

Pressure limitations of other completions equipment o Intervention

Intervention cost for Deepwater Tubing trip Valve trip

KOT & Running and Pulling tools Gas-lift equipment for high pressure/temperature

o Limitations of 1.5” gas lift valveso Latcheso SPMo Non-metallicso Back-check

Design approach for developing HPHT GL equipmento Operators and service providers must work togethero Utilization of subject matter experts (SME) FEA / strain gauge, CFD, material, welding etc.o Can we learn from other industries and increase product reliability?o Develop fit for purpose standards that use SME input in conjunction with existing standards

Conclusion

Notes:

mailto:[email protected]


2016 Gas-Lift WorkshopTechnical PresentationsSession: 4 Status of API Standards, API Gas-Lift, and Other Items

Session Chairs: Tommy Hunt, Rick Haydel

Presentation Title: 4 – 1Novel Use of Dual Completion for Gas Lift Deepening

Company(ies): Brunei Shell Petroleum

Author(s): K. SontiF.SuhaiminJ.W. Hall


Abstract:The producing oil fields located offshore Brunei consist of many dual string oil producers. The majority of these wells have been producing for over 20+ years wherein reservoir pressure has decreased and gas-lift is used as the primary means of artificial lift. The gas-lift injection depth is typically limited by the production packer, which limits also the drawdown which can be applied to the reservoir and resultant oil production. In moderate to high quality reservoirs with sufficient remaining reserves, increasing the depth of injection (TVD) is expected to yield significant oil gain. A retro-fit gas-lift system is generally considered for such applications and is typically installed on coiled tubing, which can be a significant investment in offshore environments.

This paper describes the use of the non-productive short string in Well 1 to increase depth of injection in the long string to the SSD depth below packer. All open zones are commingled and produced via the long string. A sequence of wireline operations was carried out on both strings to alter the injection path. The main advantages of this method are its simplicity and low cost. As it only modifies the gas-lift valve string, it still retains access to the reservoir unlike a retro-fit system. Additionally, the well head pressure on the short string acts is used to calculate the flowing bottom-hole pressure (FBHP), which gives critical information on well performance. As a result of this method, the oil production in Well 1 increased by 40% and is currently being replicated across the field in suitable candidates. Additional opportunity to deploy chemicals (e.g.: foamers) via the short string is also being considered. Notes:




Presentation Title: 4 – 2Status Review: API Specifications and Recommended Practices for Gas-Lift

Company(ies): McCalvin Enterprises

Author(s): David McCalvin


Abstract:Many of the Gas-Lift related API Specifications are currently under review and refinement and their status may have an impact on future regulations and product supply. In the current regulation environment new and updated product and operations documents are viewed with increased interest by the regulator community. Reference to API and ISO standards are becoming recognized as of good value and their adoption in government documents appears to be gaining momentum. Therefore, participation in the preparation and refinement of these documents becomes more important than ever. This presentation will review the key points of the Specifications and Recommended Practices which are actively in revision and their projected completion targets. Notes:




Presentation Title: 4 – 3Field Trial in Alaska of 1-Inch Barrier Gas-Lift Valve

Company(ies): Schlumberger

Author(s): Phillip Hodge


Abstract:Objective and ScopeMany of the wells in Prudhoe Bay are completed with 4-1/2” tubing and slimhole side pocket mandrels with 1” pockets. Gas injection rates for these completions are often very high resulting in more frequent interventions to change out damaged gas lift valves, and damage to the gas lift mandrel itself. BP in Alaska is working with Schlumberger to field trial the 1” barrier qualified gas lift valves in the effort to prove whether the barrier technology can provide value by reducing operating cost by:

a. Reduce the frequency of valve change outs.b. Reduce velocity through the valve, or better withstand the existing flow rates.c. Eliminate the need to run straddle pack-offs by preventing damage to gas lift mandrels

Method Procedures and ProcessSince 2003, the client has tracked gas lift valve change outs related to mechanical failures, as well as tracking failures of gas lift mandrels due to flow erosion of the pocket. The result is that there have been 271 valve change outs on 227 wells total due to flow erosion of the valve. Two candidate wells were chosen with a history of a gas lift valve change interventions due valve erosion and we installed two pressure operated 1” barrier gas lift valves and one 1” barrier orifice valve in the existing Well 13-14 and a barrier orifice valve in Well X-10.

Results, Observations, and ConclusionsThe valves passed the shop set up and valve installation with no issues in both wells, and positive wellbore integrity tests upon installation. Well 13-14 later passed an integrity test after 60 days, and the valve was pulled after 90 days. This presentation will show a generic comparison of well performance before and after the field trial valves were installed, and the gas lift design analysis for both wells.Notes:




Presentation Title: 4 – 4Issues Associated with Selection and Use of Gas-Lift in Deep Water, High Pressure, High Temperature Applications

Company(ies): Shell International EP

Author(s): Wayne Mabry


In deep water, high pressure and high temperature applications, the type of artificial lift selected is dependent on many issues. These issues include the produced fluids, type and depth of formations, pressure maintenance selection, depth of water, distance to host, and maturity of reliable lift equipment to list a few. Surface infrastructure is also a key consideration in artificial lift selection as different AL methods have different foot print requirements. Once gas-lift is selected for deep water and/or high pressure/high temperature (HPHT), there are multiple issues that are not commonly encountered in most gas-lift applications that must be thoroughly explored and understood. Solutions must be developed for inclusion in the operating schemes to assure success throughout the assets life. A few of these include field infrastructure, well design; as well as intervention and operational tactics. The entire operating system must be properly understood to eliminate unforeseen events that may compromise well and system integrity and impact production/recoverable reserves.

This presentation will briefly review some of these issues associated with deep water and/or HPHT applications to provide a clearer understanding of the magnitude of the issues involved.Notes:

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