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.

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 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.

Low Well Cost: Effective Cost Optimisation for Marginal Green Field Development Using Fit-for-Purpose Well Design

2021 ◽  
Author(s):  
Thivyashini Thamilyanan ◽  
Hasmizah Bakar ◽  
Irzee Zawawi ◽  
Siti Aishah Mohd Hatta
Keyword(s):  
Cost Effective ◽  
Second Phase ◽  
Sand Production ◽  
Field Development ◽  
Well Completion ◽  
Artificial Lift ◽  
Sand Control ◽  
Fit For Purpose ◽  
Reservoir Connectivity ◽  
Gas Lift

Abstract During the low oil price era, the ability to deliver a small business investment yet high monetary gains was the epitome of success. A marginal field with its recent success of appraisal drilling which tested 3000bopd will add monetary value if it is commercialized as early as possible. However, given its marginal Stock Tank Oil Initially in Place (STOIIP), the plan to develop this field become a real challenge to the team to find a fit-for-purpose investment to maximize the project value. Luxuries such as sand control, artificial lift and frequent well intervention need to be considered for the most cost-effective measures throughout the life of field ‘Xion’. During field development study, several development strategies were proposed to overcome the given challenges such as uncertainty of reservoir connectivity, no gas lift supply, limited footprint to cater surface equipment and potential sand production. Oriented perforation, Insitu Gas Lift (IGL), Pressure Downhole Gauge (PDG), Critical Drawdown Pressure (CDP) monitoring is among the approaches used to manage the field challenges will be discussed in this paper. Since there are only two wells required to develop this field, a minimum intervention well is the best option to improve the project economics. This paper will discuss the method chosen to optimize the well and completion strategy cost so that it can overcome the challenges mentioned above in the most cost-effective approach. Artificial lift will utilize the shallower gas reservoirs through IGL in comparison to conventional gas lift. Sand Production monitoring will utilize the PDG by monitoring the CDP. The perforation strategy will employ the oriented perforation to reduce the sand free drawdown limit compare to the full perforation strategy. The strategy to monitor production through PDG will also reduce the number of interventions to acquire pressure data in establishing reservoir connectivity for the second phase development through secondary recovery and reservoir pressure maintenance plan. This paper will also explain the innovative approaches adopted for this early monetization and fast track project which is only completed within 4 months. This paper will give merit to petroleum engineers and well completion engineers involved in the development of marginal fields.

scholarly journals GAS LIFT OPTIMIZATION OF A MATURE WELL IN NIGER DELTA, NIGERIA USING INCOMPLETE DATASET: A CASE STUDY

2020 ◽  
Vol 4 (1) ◽  
pp. 15-18
Author(s):  
Oghenegare E. Eyankware ◽  
Idaereesoari Harriet Ateke ◽  
Okonta Nnamdi Joseph
Keyword(s):  
Niger Delta ◽  
Gas Injection ◽  
Injection Rate ◽  
Wellhead Pressure ◽  
Well Production ◽  
Artificial Lift ◽  
Lift Mechanism ◽  
Fluid Production ◽  
Water Cut ◽  
Gas Lift

Well DEF, a well located in Niger Delta region of Nigeria was shut down for 7 years. On gearing towards re-starting production, different options such as installation of gas lift mechanism, servicing and installation of packers and valves were evaluated for possibility of increasing well fluid productivity. Hence, this research was focused on optimizing well fluid productivity using PROSPER through installation of continuous gas lift mechanism on an existing well using incomplete dataset; in addition, the work evaluated effect of gas injection rates, wellhead pressure, water cut and gas gravity on efficiency of the artificial lift mechanism for improved well fluid production. Results of the study showed that optimum gas injection rate of 0.6122 MMscf/day produced well fluid production of 264.28 STB/day which is lower than pristine production rate (266 STB/day) of the well. Also, increment in wellhead pressure resulted in decrease in well production, increase in water cut facilitated reduction in well fluid productivity while gas gravity is inversely proportional to well fluid productivity. Based on results obtained, authors concluded that Well DEF does not require gaslift mechanism hence, valves and parkers need to be re-serviced and re-installed for sustained well fluid.

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.

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>

Comprehensive Approach to Tackle Systemic Failure in Gas Lift Valves in Pre Salt Wells

2021 ◽  
Author(s):  
Elaine Daniele M P C Real ◽  
Thiago Geraldo Silva ◽  
Otavio Borges Ciribelli ◽  
Tatiana Sanomya
Keyword(s):  
Failure Process ◽  
Comprehensive Approach ◽  
Fluid Composition ◽  
Artificial Lift ◽  
Production Wells ◽  
Production History ◽  
Early Failures ◽  
Water Cut ◽  
The Impact ◽  
Gas Lift

Abstract This work describes a comprehensive approach to tackle systemic failure in gas lift valves in pre-salt wells. Failure analyses in gas lift valves were performed after unexpected early failures leading to tubing-annulus communication. Understanding the root causes of this problem generates value for assets, increasing equipment life, preventing unnecessary workover, and reducing costs. Suspect failed valves are systematically removed from the wells, usually by slick-line workovers, and brought to an onshore workshop, where their integrity and mechanical functionality can be analyzed. The valve's run life, equipment model and manufacturer, annular fluid, flow through the gas lift valve, operational pressure and temperature, composition of reservoir fluids and solids deposition were verified. Besides, transient simulations were carried out to provide insights on the root causes of the failure. Also, a good understanding on how each valve works, including its engineering design, was necessary to thoroughly understand the failure process. The study of gas-lift injection valves early failure in pre-salt wells have been an excellent way to understand the life cycle of production wells before the need to start lift gas injection. That leads to a comprehensive understanding about the effects of the fluids left in annulus and have supported Petrobras in most effectively managing of well integrity and workover costs. The analysis incorporates the impact of oil production, water cut, completion type, annular fluid composition, anti-scaling fluid injection (composition and efficiency) and the differential pressure between the tubing of the annulus in the valve failure model. The composition of the deposit found inside the valves and the production history of the well were essential to assemble the puzzle of how the failure mechanism works. With the acquired knowledge, it has been possible to apply barriers to avoid future events of unwanted tubing-annulus communication arising from gas-lift valve failures. This article provides a methodology and examples for a most effective understanding of the gas-lift valves failure mechanisms and their root causes, which proved to be a valuable tool for the artificial lift design and for the planning of well operations. That has contributed to maximize equipment life, cost reduction and, at last, generating value for the company.

scholarly journals Design and Economic Evaluation of the ESP and Gas Lift on the Dead Oil Well

2018 ◽  
Vol 8 (6) ◽  
Author(s):  
Imran A. Hullio ◽  
Sarfraz A. Jokhio ◽  
Khalil Rehman Memon ◽  
Sohail Nawab ◽  
Khair Jan Baloch
Keyword(s):  
Capital Budgeting ◽  
Production Performance ◽  
Oil Well ◽  
Production Rates ◽  
Production Forecast ◽  
Artificial Lift ◽  
Operating Expenditures ◽  
Water Cut ◽  
Gas Lift ◽  
Design And Production

Owing to the increasing water cut and decreasing in reservoir pressure of the well, the oil production of the well has seized and the well has become dead. This research study evaluates the implementation of the artificial lift methods ESP and Gas Lift- economically and technically on the well by using the production performance software (PROSPER) and economical yardsticks (NPV and ROI). The theory, design, production forecast, capital and operating expenditures of the electric submersible pump and gas lift are discussed for the appropriate selection of any of two options. The PROSPER software is used as the simulation tool for the design and production forecasting of the ESP and Gas Lift based. The ESP and Gas Lift methods have been simulated for the design and production forecast by entering the reservoir and completion inputs in the software. Subsequently, the software has been simulated to run on different sensitivities of the variables such as water cut, wellhead pressure setting depth, operating frequency and gas injection rates to check the production rates at different scenarios. Having performed the production performance simulation on the selected artificial lift methods, the methods have been investigated by capital budget-ing. In capital budgeting, the capital and operating expenditures of both lift methods were evaluated by determining their discounted value (NPV) and re-turn on investment (ROI). The prime objective of the research is to accomplish maximum production rates and profitability by selecting the most appropriate artificial lift method for the well; as a consequence it is concluded that the suitable artificial lift method for a well can be selected by applying the simulation and economical schemes.

New Paradigm for State Department of Transportation Environmental Initiatives: New York State’s Guidelines and Procedures

2000 ◽  
Vol 1702 (1) ◽  
pp. 92-96 ◽  
Author(s):  
Gary McVoy ◽  
Mark Sengenberger ◽  
Elizabeth Novak
Keyword(s):  
New York ◽  
New York State ◽  
Cost Effective ◽  
State Department ◽  
Regulatory Compliance ◽  
Environmental Benefits ◽  
Environmental Damage ◽  
York State Department ◽  
Department Of Transportation ◽  
New Paradigm

Public-works agencies have an obligation to enhance the environment as opportunities arise. The New York State Department of Transportation (NYSDOT) has developed an environmental initiative to make an affirmative contribution to the environment, using the department’s organizational strengths. The environmental initiative is a paradigm shift applicable to all departments of transportation (DOTs). Conventional reactive regulatory compliance can reduce unnecessary environmental damage and sometimes gain grudging regulatory agency cooperation; however, it is not a positive, satisfying way of doing the people’s work. Through proactive steps, NYSDOT has become an important part of the state’s environmental solution (often at little or no additional cost) and has changed its working relationships with environmental agencies and groups. As these agencies and groups have become partners, instead of adversaries, permit-approval times have improved, mitigation costs have declined, morale has improved, and cost-effective environmental benefits are being realized. Procedures are outlined to apply the engineering capabilities of a DOT to the environmental-stewardship responsibilities shared by all governmental organizations.

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