scholarly journals Optimisation of Artificial Lifts Using Prosper Nodal Analysis for BARBRA-1 Well in Niger Delta

2020 ◽  
Vol 17 (3) ◽  
pp. 150-155
Author(s):  
Tega Odjugo ◽  
Yahaya Baba ◽  
Aliyu Aliyu ◽  
Ndubuisi Okereke ◽  
Lekan Oloyede ◽  
...  
Keyword(s):  
Niger Delta ◽  
Hydrocarbon Exploration ◽  
Productivity Index ◽  
Submersible Pump ◽  
Well Performance ◽  
Power Losses ◽  
Nodal Analysis ◽  
Artificial Lift ◽  
Electrical Submersible Pump ◽  
Gas Lift

Hydrocarbon exploration basically requires effective drilling and efficient overpowering of frictional and viscosity forces. Normally, frictional power losses occur in deep well systems and it is essential to analyse each component of any well system to determine where exactly pressure is lost, and this can be done using Nodal Analysis. In this study, nodal analysis has been carried out with the use of PROSPER, a software for well performance, design and optimisation. Artificial lifts can then be used to solve the problem of frictional power losses. To increase the production of Barbra 1 well in the Niger Delta and hence extend its functional life, we have applied nodal analysis. Modelling results for three artificial lift methods; continuous gas lift, intermittent gas lift and electrical submersible pump were found to be 1734.93 bbl/day, 451.50 bbl/day and 2869 bbl/day respectively. The output from the well performance without artificial lift was 1370.99 bbl/day by applying Darcy’s model. Meanwhile, the output from the well without artificial lift is 89.90 bbl/day when aided with productivity index (PI) entry, the normal model for intermittent gas lift. Hence, from the comparative analysis of the results obtained from this study, it was deduced that when artificial lifts are employed, the well output increases significantly from 1370.99bbl/day to 2869 bbl/day (electrical submersible pump). This study concludes that wells such as Barbra 1 are good candidates for artificial lift, and this is evidenced by increasing productivity. Keywords: Production optimisation, nodal analysis, prosper simulator and barbra well.

Evaluating Alternate Artificial Lift Methods in the Niger Delta

2021 ◽  
Author(s):  
Priscilla Enwere ◽  
Ademola Amusa ◽  
Oluwafemi Olominu ◽  
Nchekwube Lazson ◽  
Emmanuel Mbonu ◽  
...  
Keyword(s):  
Niger Delta ◽  
Selection Criteria ◽  
Selection Criterion ◽  
Network Models ◽  
Submersible Pump ◽  
Artificial Lift ◽  
Electrical Submersible Pump ◽  
Water Cut ◽  
Surface Production ◽  
Gas Lift

Abstract Gas lift is currently being utilized as the artificial lift system in OML Z, this has been so for the last thirty years. Although, the field has seen significant increase in production rates in recent times, gas lift requirement has increased with increase in production and water cut. To maximize production and value from OML Z, it is expedient to seek an alternative artificial lift method that can debottleneck and unlock the potential of fields within OML Z where production has been less than 50% since the field was brought on stream. Production from the gas lifted fields within OML Z is constrained by a combination of bottlenecked gas lift facility and surface production facility. This study explores the different artificial lift methods and selects an applicable technology for OML Z using a developed selection criterion. Electrical Submersible Pump (ESP) found suitable for OML Z is further analyzed for feasibility and application within OML Z given existing limitations. The candidate reservoir and well selection criteria are elaborated upon, taking into consideration several elements that contribute to the production process. The results of the well and network models, that shows the significant gains attributed to the conversion of selected previously gas lifted wells to ESPs, are discussed. The economic benefit of such conversion is also shown.

Pushing 30 Years Multiple Brown Fields Limits Through Artificial Lift and Facilities Improvement

2021 ◽  
Author(s):  
Mohd Hafizi Ariffin ◽  
Muhammad Idraki M Khalil ◽  
Abdullah M Razali ◽  
M Iman Mostaffa
Keyword(s):  
New Technology ◽  
Lessons Learned ◽  
Oil Fields ◽  
Submersible Pump ◽  
Large Space ◽  
Gas Well ◽  
Wellhead Pressure ◽  
Artificial Lift ◽  
Electrical Submersible Pump ◽  
Gas Lift

Abstract Most of the oil fields in Sarawak has already producing more than 30 years. When the fields are this old, the team is most certainly facing a lot of problems with aging equipment and facilities. Furthermore, the initial stage of platform installation was not designed to accommodate a large space for an artificial lift system. Most of these fields were designed with gas lift compressors, but because of the space limitation, the platforms can only accommodate a limited gas lift compressor capacity due to space constraints. Furthermore, in recent years, some of the fields just started with their secondary recovery i.e. water, gas injection where the fluid gradient became heavier due to GOR drop or water cut increases. With these limitations and issues, the team needs to be creative in order to prolong the fields’ life with various artificial lift. In order to push the limits, the team begins to improve gas lift distribution among gas lifted wells in the field. This is the cheapest option. Network model recommends the best distribution for each gas lifted wells. Gas lifted wells performance highly dependent on fluid weight, compressor pressure, and reservoir pressure. The change of these parameters will impact the production of these wells. Rigorous and prudent data acquisitions are important to predict performance. Some fields are equipped with pressure downhole gauges, wellhead pressure transmitters, and compressor pressure transmitters. The data collected is continuous and good enough to be used for analysis. Instead of depending on compressor capacity, a high-pressure gas well is a good option for gas lift supply. The issues are to find gas well with enough pressure and sustainability. Usually, this was done by sacrificing several barrels of oil to extract the gas. Electrical Submersible Pump (ESP) is a more expensive option compared to a gas lift method. The reason is most of these fields are not designed to accommodate ESP electricity and space requirements. Some equipment needs to be improved before ESP installation. Because of this, the team were considering new technology such as Thru Tubing Electrical Submersible Pump (TTESP) for a cheaper option. With the study and implementation as per above, the fields able to prolong its production until the end of Production Sharing Contract (PSC). This proactive approach has maintained the fields’ production with The paper seeks to present on the challenges, root cause analysis and the lessons learned from the subsequent improvement activities. The lessons learned will be applicable to oil fields with similar situations to further improve the fields’ production.

scholarly journals OPTIMASI PRODUKSI SUMUR EC-6 DENGAN MEMBANDINGKAN PENGANGKATAN BUATAN GAS LIFT DAN ELECTRIC SUBMERSIBLE PUMP

PETRO ◽  
2019 ◽  
Vol 8 (1) ◽  
pp. 8
Author(s):  
Jonathan Jonathan ◽  
Sisworini Sisworini ◽  
Samsol Samsol ◽  
Hari Oetomo
Keyword(s):  
Production System ◽  
Gas Injection ◽  
Pipe Diameter ◽  
Submersible Pump ◽  
Reservoir Stimulation ◽  
Artificial Lift ◽  
Sucker Rod ◽  
Electrical Submersible Pump ◽  
Gas Lift ◽  
Electric Submersible Pump

<em>In the world of oil is very common in the production system. This production system produces oil from wells after drilling and well compressions. Over time, the production of a well may decrease due to several parameters of pressure drop and the presence of clay which makes the pipe diameter narrower. There are several methods used to increase the decrease in production including adding artificial lifts such as sucker rod pump, electric submersible pump and gas lift, reservoir stimulation and pipe cleaning if the pipe diameter is reduced due to clay. The well has been installed an artificial lift is a gas lift and this well need an optimization to increase its production. The EC-6 well optimization is planned by comparing the lift-up scenario of the gas lift by adjusting the rate of gas injection and deepening the orifice injection and also an installation of electrical submersible pump. Best percentage of optimization production from EC-6 Well, last scenario is chosen which is new installation artificial lift ESP from gas lift (existing) and gaining 18.52% form existing production</em>

scholarly journals The Critical Investigation on Essential Parameters to Optimize the Gas Lift Performance In “J” Field Using Prosper Modelling

2018 ◽  
Vol 7 (2) ◽  
pp. 46-54
Author(s):  
Fitrianti Fitrianti ◽  
Dike Fitriansyah Putra ◽  
Desma Cendra
Keyword(s):  
Well Being ◽  
Production Optimization ◽  
Productivity Index ◽  
Injection System ◽  
Driving Mechanism ◽  
Well Performance ◽  
Artificial Lift ◽  
Index Value ◽  
Gas Lift ◽  
Selection Of

The declining reservoir, oil production and pressure depletion with the well being produced, the results of the investment of the well will also decrease. For that there needs to be energy that can help to lift the fluid to the surface. One of the artificial lift methods that can be used is a gas lift. Gas lift is a method commonly used when there is a natural gas source as an injection gas supply. The selection of the artificial lift method is based on several considerations, namely the reservoir conditions, fluid conditions, well conditions, conditions on the surface, availability of electricity, availability of gas, and sand problem. The influential parameters in the selection of gas lifts include: Productivity Index (PI), Gas Liquid Ratio (GLR), depth of the well and driving mechanism from the reservoir. The Gas Lift that the production optimization wants to do is the injection system in a Continuous Gas Lift. Used in wells that have a high Productifity Index value. Where in the LB field to be analyzed, the Productifity Index value is 2.0 bpd / psi. This study intends to optimize a gaslift well performance as an effort to maximize the results of well production. Based on the research that has been done using Prosper Modeling on the “J” field, the following conclusions are obtained the effect of pressure and viscosity on the gas lift well flow rate in this condition can be said to be efficient, because the conditions / pressure given at temperatures below 300 F can reach the miscible condition and from the results of determining the optimal conditions to get the best well performance, obtain an optimal liquid rate of 1829.4 STB / D with an oil rate of 36.6 STB / D.   Keywords: Gas lift, Optimization, Immiscible Pressure, Viscosity

Corrosion Challenges on Electrical Submersible Pump Wells in the North Kuwait Field

2021 ◽  
Author(s):  
Abdullatif Al-Majdli ◽  
Carlos Caicedo Martinez ◽  
Sarah Al-Dughaishem
Keyword(s):  
Submersible Pump ◽  
Stray Current ◽  
The North ◽  
Artificial Lift ◽  
Steel Tubing ◽  
Electrical Submersible Pump ◽  
Historic Data ◽  
Corrosion Resistant Alloy ◽  
Galvanic Couples ◽  
Sweet Corrosion

Abstract Oil production in North Kuwait (NK) asset highly relies on artificial lift systems. The predominant method of artificial lift in NK is electrical submersible pump (ESP). Corrosion is one of the major issues for wells equipped with ESP in NK field. Over 20% of the all pulled ESPs in 2019 and 2020 in NK field were due to corrosion of the completion or the ESP string. With an increase in ESP population in NK, a proactive corrosion mitigation is essential to reduce the number of ESP wells requiring workover. Historic data of the pulled ESPs in NK revealed that most of the corrosion cases were found in the tubing as opposed to the ESP components. Although there are multiple factors that can cause corrosion in NK, the driving force was identified to be the presence of CO2 (sweet corrosion). Corrosion rates have been enhanced by other factors such as stray current and galvanic couples. In this paper, multiple methods have been suggested to minimize and prevent the corrosion issue such as selecting the optimal completion and ESP metallurgy (ex. corrosion resistant alloy), installing internally glass reinforced epoxy lined carbon steel tubing, and installing a sacrificial anode whenever applicable.

Experimental Study and Modeling of Heating Effect in Electrical Submersible Pump Operating With Ultra-Heavy Oil

2018 ◽  
Author(s):  
Jorge Luiz Biazussi ◽  
Cristhian Porcel Estrada ◽  
William Monte Verde ◽  
Antonio Carlos Bannwart ◽  
Valdir Estevam ◽  
...  
Keyword(s):  
Heavy Oil ◽  
Critical Factor ◽  
High Viscosity ◽  
Inlet Temperature ◽  
Outlet Temperature ◽  
Heating Effect ◽  
Submersible Pump ◽  
Oil Viscosity ◽  
Artificial Lift ◽  
Electrical Submersible Pump

A notable trend in the realm of oil production in harsh environments is the increasing use of Electrical Submersible Pump (ESP) systems. ESPs have even been used as an artificial-lift method for extracting high-viscosity oils in deep offshore fields. As a way of reducing workover costs, an ESP system may be installed at the well bottom or on the seabed. A critical factor, however, in deep-water production is the low temperature at the seabed. In fact, these low temperatures constitute the main source for many flow-assurance problems, such as the increase in friction losses due to high viscosity. Oil viscosity impacts pump performance, reducing the head and increasing the shaft power. This study investigates the influence of a temperature increase of ultra-heavy oil on ESP performance and the heating effect through a 10-stage ESP. Using several flow rates, tests are performed at four rotational speeds and with four viscosity levels. At each rotational speed curve, researchers keep constant the inlet temperature and viscosity. The study compares the resulting data with a simple heat model developed to estimate the oil outlet temperature as functions of ESP performance parameters. The experimental data is represented by a one-dimensional model that also simulates a 100-stage ESP. The simulations demonstrate that as the oil heat flows through the pump, the pump’s efficiency increases.

Cable Thru Downhole Insert Safety Valve: A New Paradigm

2021 ◽  
Author(s):  
Kuswanto Kuswanto ◽  
Oka Fabian ◽  
Orient B Samuel ◽  
Mohd Yuzmanizeil B Yaakub ◽  
Chua Hing Leong ◽  
...  
Keyword(s):  
Safety Valve ◽  
Cost Effective ◽  
Submersible Pump ◽  
New Paradigm ◽  
Reservoir Properties ◽  
Technology Application ◽  
Artificial Lift ◽  
Water Cut ◽  
The Right ◽  
Gas Lift

Abstract The B Field is located in the South China Sea, about 45 KM offshore Sarawak, Malaysia, in a water depth approximately 230 ft. Its structure is generally regarded as a gentle rollover anticline with collapsed crest resulting from growth faulting. The reservoirs were deposited in a coastal to shallow marine with some channels observed. Multiple stacked reservoirs consist of a series of very thick stacked alternating sandstone and minor shale layers with differing reservoir properties. The shallow zones are unconsolidated, and the wells were completed with internal gravel packs. Wells in B Field mostly were completed in multi-layered reservoirs as dual strings with SSDs and meant to produce as a commingled production. The well BX is located within B Field and designed as oil producer well with a conventional tubing jointedElectrical Submersible Pump (ESP) system which was installed back in 2008. Refer to figure 1, the initial completion schematic is 3-1/2″ single string that consist of the single production packer, gas lift mandrel, tubing retrievable Surface Controlled Subsurface Safety Valve (SCSSV) and ESP. The production packers equipped with the feed thru design to accommodate the ESP cable and the gas vent valve as part of the ESP completion design. The gas lift mandrel was installed in the completion string as a backup artificial lift method to receive the gas lift and orifice valve in the event of the conventional ESP failed. Hence the well still able to produce by introducing the gas thru the annulus to activate the gas lift valve. Eventually throughout the end of the the field life, the well would depend on the ESP system for the primary lifting method due to gas lift depth limitation and the gas supply. The conventional ESP failed after seven years of operation which is above the average ESP lifetime. The well last produced at a flow rate with 28 % water cut, however the well is not at the end of the field life. Based on the economical study with the right technology and cost efficient approach, the well still economicaly profitable. The Thru Tubing (TT) ESP technology is approached as cost effective solution compare to fully well workover. Despite a couple of operational challenges, for example, setting the cable hanger, maintaining downhole barrier requirement, the Thru Tubing Electrical Submersible Pump Cable Deployed (TTESP CD) and Cable Thru Insert Safety Valve (CT-ISV) was successfully installed. Several post-installation findings have uncovered some problems which are requiring some additional technical and operation improvement for future similar applications. This paper will highlight the deployment of the Cable Thru Insert Safety Valve (CT-ISV) that was successfully installed as pilot, which is the first application in the world, and also highlights the success, lesson learnt and improvement for future requirement for the CT-ISV application as one of the solution for retrofitting completion application without jeopardizing the well integrity. This achievement is collaboration between Company and service partner as the technology and deployment under the proprietary scope. Further technology application, the replication of this insert safety valve was conducted and successfully deployed on other three wells.

scholarly journals Electrical Submersible Pump Design in Vertical Oil Wells

2020 ◽  
Vol 4 (4) ◽  
pp. 1-7
Author(s):  
Gomaa S
Keyword(s):  
Oil Wells ◽  
Maintenance Cost ◽  
Oil Well ◽  
Submersible Pump ◽  
Reservoir Properties ◽  
Pump Design ◽  
Artificial Lift ◽  
Complete Study ◽  
Electrical Submersible Pump

Artificial Lift is a very essential tool to increase the oil production rate or lift the oil column in the wellbore up to the surface. Artificial lift is the key in case of bottom hole pressure is not sufficient to produce oil from the reservoir to the surface. So, a complete study is carried to select the suitable type of artificial lift according to the reservoir and wellbore conditions like water production, sand production, solution gas-oil ratio, and surface area available at the surface. Besides, the maintenance cost and volume of produced oil have an essential part in the selection of the type of artificial lift tool. Artificial lift tools have several types such as Sucker Rod Pump, Gas Lift, Hydraulic Pump, Progressive Cavity Pump, Jet Pump, and Electrical Submersible Pump. All these types require specific conditions for subsurface and surface parameters to apply in oil wells. This paper will study the Electrical Submersible Pump “ESP” which is considered one of the most familiar types of artificial lifts in the whole world. Electrical Submersible Pump “ESP” is the most widely used for huge oil volumes. In contrast, ESP has high maintenance and workover cost. Finally, this paper will discuss a case study for the Electrical Submersible pump “ESP” design in an oil well. This case study includes the entire well and reservoir properties involving fluid properties to be applied using Prosper software. The results of the design model will impact oil productivity and future performance of oil well.

scholarly journals ANALISA OPTIMASI GAS LIFT PADA SUMUR RS-1 DI LAPANGAN RS

PETRO ◽  
2019 ◽  
Vol 7 (3) ◽  
pp. 127
Author(s):  
Rachmi Septiani ◽  
Muh Taufiq Fathaddin ◽  
Djoko Sulistyanto
Keyword(s):  
Productivity Index ◽  
Net Income ◽  
Artificial Lift ◽  
Gas Lift

<p>Sumur RS-1 adalah sumur yang tidak mampu lagi untuk memproduksikan fluidanya secara sembur alam, sehingga membutuhkan instalasi <em>artificial lift</em>. Untuk produksi harian, sumur tersebut dibantu oleh <em>artificial lift </em>jenis <em>continuous gas lift</em>. Dengan bantuan <em>gas lift</em>, Sumur RS-1 dapat berproduksi selama beberapa tahun. Produksi tertinggi untuk Sumur RS-1 adalah sebesar 273 BFPD. Sumur RS-1 memiliki 3 <em>gas lift valve </em>dengan titik kedalaman injeksi berada pada kedalaman 2.743 ft. Dalam studi ini dilakukan analisia optimasi penggunaan <em>artificial lift </em>yang sudah terpasang yaitu <em>continuous gas lift</em>. Sumur RS-1 memiliki <em>watercut </em>diatas 50%, oleh karena itu, pembuatan grafik IPR Sumur RS-1 menggunakan <em>composite </em>IPR. Maka didapat nilai <em>productivity index </em>Sumur RS-1 sebesar 0,71. Optimasi Sumur RS-1 ini dilakukan dengan meningkatan laju alir gas injeksinya dari 0,002 mmscfd menjadi 0,2 mmscfd karena menghasilkan <em>net income </em>yang paling tinggi yaitu 1.979 USD/d dengan pertambahan <em>oil rate </em>yang awalnya sebesar 33,9 STB/d menjadi sebesar 65,2 STB/d.</p>

scholarly journals The EVALUATION AND OPTIMIZATION OF ELECTRICAL SUBMERSIBLE PUMP WELLS THAT HAVE A HIGH PI USING VARIABLE SPEED DRIVE WITH FREQUENCY ABOVE 60HZ IN "X" FIELD "Y" WELLS (EVALUASI DAN OPTIMISASI SUMUR ELECTRICAL SUBMERSIBLE PUMP YANG MEMILIKI PI TINGGI DENGAN MENG

2021 ◽  
Vol 4 (02) ◽  
Author(s):  
Rycha Melysa
Keyword(s):  
Oil Industry ◽  
Submersible Pump ◽  
Production Potential ◽  
Artificial Lift ◽  
Natural Flow ◽  
Production Wells ◽  
Fluid Production ◽  
Electrical Submersible Pump ◽  
Electric Submersible Pump ◽  
Selection Of

The condition of a well if it is produced continuously will cause reservoir pressure to fall, and the flow rate will also go down, as a result the productivity of the well will also decrease. For this reason, there is a need for energy that can help lift fluid up to the surface. In the primary method there are 2 stages of production, namely natural flow where oil is raised directly through the tubing surface, and artificial lift is the method of obtaining oil by using the aid of additional tools. In the oil industry there are various types of artificial lifts, one of which is an electric submersible pump (ESP).   Electric Submersible Pump is an electric pump that is immersed into a liquid. This pump is made on the basis of a multilevel centrifugal pump where each level has an impeller and iffuser which aims to push the fluid to the surface. ESP planning is strongly influenced by the roductivity of production wells. The rate of fluid production influences the selection of pump type and size. This is because each pump has its own production rate based on the type and size of each pump used.   In the course of producing oil, there will certainly be a problem that will cause a decline in production, therefore it is necessary to evaluate and redesign the ESP pump, in an effort to optimize the production potential of these wells. In this study an evaluation of the performance of the electrical submersible pump will be carried out and a pump redesigned to optimize production using AutographPC software on the well X in the field Y Kondisi suatu sumur jika diproduksikan terus-menerus akan mengakibatkan tekananreservoir turun, dan laju alir akan turun pula, akibatnya produktivitas sumur akan turunjuga. Untuk itu perlu adanya tenaga yang dapat membantu mengangkat fluida sampaikepermukaan. Dalam metode primer terdapat 2 tahapan produksi yaitu natural flowdimana minyak terangkat kepermukaan langsung melalu tubing, dan artificial liftmerupakan metode perolehan minyak dengan menggunakan bantuan alat tambahan.Dalam dunia perminyakan ada berbagai macam jenis pengangkatan buatan salahsatunya adalah electric submersible pump (ESP). Electric Submersibel Pump merupakan pompa listrik yang dibenamkan kedalam cairan.Pompa ini dibuat atas dasar pompa sentrifugal bertingkat banyak dimana setiap tingkatmempunyai impeller dan diffuser yang bertujuan untuk mendorong fluida kepermukaan.Perencanaan ESP sangat dipengaruhi oleh produktivitas sumur produksi. Laju produksifluida berpengaruh terhadap pemilihan jenis dan ukuran pompa. Hal ini dikarenakantiap-tiap pompa memiliki laju produksi sendiri berdasarkan jenis dan ukuran tiap- tiappompa yang dipakai. Dalam kegiatan memproduksikan minyak tentu suatu saat akan terjadi permasalahanyang mengakibatkan menurunnya produksi, Oleh karena itu perlu dilaksanakan evaluasidan design ulang pompa ESP, sebagai upaya untuk mengoptimalkan potensi produksisumur-sumur tersebut. Pada penelitian ini akan dilakukan evaluasi kinerja electricalsubmersible pump dan melakukan desain ulang pompa untuk optimasi produksidengan menggunakan software AutographPC pada sumur X lapangan y Kata kunci: electric submersible pump, AutographPC, laju produksi

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