Gas Lift Design Optimization Using Intelligent Gas Lift Valves a KJO Case Study

Mapping Intimacies ◽

10.2118/206262-ms ◽

2021 ◽

Author(s):

Abdullah Al Qahtani ◽

Sultan Al-Aklubi ◽

Abdel BenAmara ◽

Stephen Faux

Keyword(s):

Production Rate ◽

Oil And Gas ◽

Injection Pressure ◽

Oil Wells ◽

Oil Field ◽

Added Value ◽

Well Performance ◽

Time Data ◽

Gas Lift

Abstract Gas lift is becoming a big consideration in most of oil field as an economic, sustainable means of artificially lifting weak/dead oil wells. This is especially considered in high volume wells. Gas lift is employed, by injecting gas into the well tubing through gas lift valves, to reduce the hydrostatic pressure of the produced fluid column in oil wells, leading to a lower flowing bottom-hole pressure. The increased pressure differential induced across the sand face from the in situ reservoir pressure, assists in lifting the produced fluid to the surface. Optimizing the level of injected gas is important in maximizing the production, and hence the financial performance of the well. The challenge for most oil and gas producers is that they do not effectively maximize production with the most efficient use of gas lift resources. The challenge is that there is a lack of accurate and timely production data from the well tests. The optimal inject rate for a well is based on a ratio of injected gas rate to the liquid production rate. Under injecting the gas decreases the well production rate. The objective of optimization in gas-lifted wells is to achieve optimal production rate with minimal gas injection volume to spare gas for other wells, when the compression capacity is limited. Optimally allocated injection gas helps reduce unnecessary strain on your facility and maximize performance, this in turn enhances the life of production assets significantly. This paper presents a case study from Khafji Joint Operation fields, utilizing the intelligent digital gas lift valve to optimize the design and performance of the gas lift wells. The case study demonstrates the value proposition by using the digital intelligent gas lift system to maximize well performance whilst reducing injected gas, in addition to acquired real-time data that help assess the process. That optimization was achieved on well level by optimizing the well parameters such as point of injection, injection rate, and injection pressure. All these aspects have been investigated and presented in this study by using field data and flow simulations. Results showed the potential added value of the system.

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IMPACT OF GAS LIFT INJECTION RATE ON OIL PRODUCTION RATE

Scientific Journal of Applied Sciences of Sabratha University ◽

10.47891/sabujas.v0i0.76-94 ◽

2021 ◽

pp. 76-94

Author(s):

Dr. Mohamed A. GH. Abdalsadig

Keyword(s):

Real Time ◽

Energy Demand ◽

Oil And Gas ◽

Injection Pressure ◽

Production Operation ◽

Well Performance ◽

Time Data ◽

Daily Work ◽

Wellhead Pressure ◽

Gas Lift

As worldwide energy demand continues to grow, oil and gas fields have spent hundreds of billions of dollars to build the substructures of smart fields. Management of smart fields requires integrating knowledge and methods in order to automatically and autonomously handle a great frequency of real-time information streams gathered from those wells. Furthermore, oil businesses movement towards enhancing everyday production skills to meet global energy demands signifies the importance of adapting to the latest smart tools that assist them in running their daily work. A laboratory experiment was carried out to evaluate gas lift wells performance under realistic operations in determining reservoir pressure, production operation point, injection gas pressure, port size, and the influence of injection pressure on well performance. Lab VIEW software was used to determine gas passage through the Smart Gas Lift valve (SGL) for the real-time data gathering. The results showed that the wellhead pressure has a large influence on the gas lift performance and showed that the utilized smart gas lift valve can be used to enhanced gas Lift performance by regulating gas injection from down hole.

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Artificial Intelligence Assisted Well Portfolio Optimization - An Automated Reservoir Management Advisory System to Maximize the Asset Value - Case Study from ADNOC Onshore

10.2118/207274-ms ◽

2021 ◽

Author(s):

Subba Ramarao Rachapudi Venkata ◽

Nagaraju Reddicharla ◽

Shamma Saeed Alshehhi ◽

Indra Utama ◽

Saber Mubarak Al Nuimi ◽

...

Keyword(s):

Machine Learning ◽

Hybrid Approach ◽

Simulation Models ◽

Production Optimization ◽

Added Value ◽

Risk Scores ◽

Well Performance ◽

Field Development ◽

Advisory System ◽

Gas Lift

Abstract Matured hydrocarbon fields are continuously deteriorating and selection of well interventions turn into critical task with an objective of achieving higher business value. Time consuming simulation models and classical decision-making approach making it difficult to rapidly identify the best underperforming, potential rig and rig-less candidates. Therefore, the objective of this paper is to demonstrate the automated solution with data driven machine learning (ML) & AI assisted workflows to prioritize the intervention opportunities that can deliver higher sustainable oil rate and profitability. The solution consists of establishing a customized database using inputs from various sources including production & completion data, flat files and simulation models. Automation of Data gathering along with technical and economical calculations were implemented to overcome the repetitive and less added value tasks. Second layer of solution includes configuration of tailor-made workflows to conduct the analysis of well performance, logs, output from simulation models (static reservoir model, well models) along with historical events. Further these workflows were combination of current best practices of an integrated assessment of subsurface opportunities through analytical computations along with machine learning driven techniques for ranking the well intervention opportunities with consideration of complexity in implementation. The automated process outcome is a comprehensive list of future well intervention candidates like well conversion to gas lift, water shutoff, stimulation and nitrogen kick-off opportunities. The opportunity ranking is completed with AI assisted supported scoring system that takes input from technical, financial and implementation risk scores. In addition, intuitive dashboards are built and tailored with the involvement of management and engineering departments to track the opportunity maturation process. The advisory system has been implemented and tested in a giant mature field with over 300 wells. The solution identified more techno-economical feasible opportunities within hours instead of weeks or months with reduced risk of failure resulting into an improved economic success rate. The first set of opportunities under implementation and expected a gain of 2.5MM$ with in first one year and expected to have reoccurring gains in subsequent years. The ranked opportunities are incorporated into the business plan, RMP plans and drilling & workover schedule in accordance to field development targets. This advisory system helps in maximizing the profitability and minimizing CAPEX and OPEX. This further maximizes utilization of production optimization models by 30%. Currently the system was implemented in one of ADNOC Onshore field and expected to be scaled to other fields based on consistent value creation. A hybrid approach of physics and machine learning based solution led to the development of automated workflows to identify and rank the inactive strings, well conversion to gas lift candidates & underperforming candidates resulting into successful cost optimization and production gain.

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The Application of Gas-Lift Injection Pressure-Operated Spring Valves in the Western Operated Area of the Prudhoe Bay Field: A Case Study

10.2118/26099-ms ◽

1993 ◽

Author(s):

G.R. Vigil ◽

G.S. Nordlander ◽

R.L. Valencia ◽

J.O. Watkins

Keyword(s):

Injection Pressure ◽

Prudhoe Bay ◽

Gas Lift

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Two-Stage Geothermal Well Clustering for Oil-to-Water Conversion on Mature Oil Fields

Geosciences ◽

10.3390/geosciences11110470 ◽

2021 ◽

Vol 11 (11) ◽

pp. 470

Author(s):

Josipa Hranić ◽

Sara Raos ◽

Eric Leoutre ◽

Ivan Rajšl

Keyword(s):

Spatial Arrangement ◽

Oil Wells ◽

Oil Field ◽

Oil Fields ◽

Two Stage ◽

Oil Companies ◽

Geothermal Potential ◽

Clustering Approach ◽

Water Cut

There are numerous oil fields that are approaching the end of their lifetime and that have great geothermal potential considering temperature and water cut. On the other hand, the oil industry is facing challenges due to increasingly stringent environmental regulations. An example of this is the case of France where oil extraction will be forbidden starting from the year 2035. Therefore, some oil companies are considering switching from the oil business to investing in geothermal projects conducted on existing oil wells. The proposed methodology and developed conversions present the evaluation of existing geothermal potentials for each oil field in terms of water temperature and flow rate. An additional important aspect is also the spatial distribution of existing oil wells related to the specific oil field. This paper proposes a two-stage clustering approach for grouping similar wells in terms of their temperature properties. Once grouped on a temperature basis, these clusters should be clustered once more with respect to their spatial arrangement in order to optimize the location of production facilities. The outputs regarding production quantities and economic and environmental aspects will provide insight into the optimal scenario for oil-to-water conversion. The scenarios differ in terms of produced energy and technology used. A case study has been developed where the comparison of overall fields and clustered fields is shown, together with the formed scenarios that can further determine the possible conversion of petroleum assets to a geothermal assets.

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NANO-SURFACTANT HUFF AND PUFF OPTIMATIZATION IN MARGINAL X FIELD USING COMMERCIAL SIMULATOR

Scientific Contributions Oil and Gas ◽

10.29017/scog.42.2.375 ◽

2019 ◽

Vol 42 (2) ◽

pp. 51-57

Author(s):

Ariel Paramastya ◽

Steven Chandra ◽

Wijoyo Niti Daton ◽

Sudjati Rachmat

Keyword(s):

Interfacial Tension ◽

Production Rate ◽

Oil Recovery ◽

Oil And Gas ◽

Oil Production ◽

Full Scale ◽

Economic Aspect ◽

Economic Optimization ◽

Single Well

Economic optimization of an oil and gas project is an obligation that has to be done to increase overall profi t, whether the fi eld is still economically feas ible or the fi eld has surpassed its economic limit. In this case, a marginal fi eld waschosen for the study. In this marginal fi eld EOR methods have been used to boost the production rate. However, a full scale EOR method might not be profi table due to the amount of resources that is required to do it. Alternatively, Huff and Puff method is an EOR technique that is reasonable in the scope of single well. The Huff and Puff method is an EOR method where a single well serves as both a producer and an injector. The technique of Huff and Puff: (1) The well isinjected with designed injection fl uid, (2) the well is shut to let the fl uid to soak in the reservoir for some time, and (3) the well is opened and reservoir fl uids are allowed to be produced. The injection fl uid (in this case, nano surfactant) is hypothesized to reduce interfacial tension between the oil and rock, thus improving the oil recovery. In this study, the application of Huff and Puff method using Nanoparticles (NPs) as the injected fl uid, as a method of improving oil recovery is presented in a case study of a fi eld in South Sumatra. The study resulted that said method yields an optimum Incremental Oil Production (IOP) in which the economic aspect gain more profi t, and therefore it is considered feasible to be applied in the fi eld.

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Innovative Gas Lift in Heavy Oil Wells: Case Study in Block 6, Sudan

10.2118/164722-ms ◽

2013 ◽

Author(s):

Tang Xueqing ◽

Li Guocheng ◽

Fahmi Abdalla Alawad ◽

Yu Keqiang ◽

Cai Bo ◽

...

Keyword(s):

Heavy Oil ◽

Oil Wells ◽

Gas Lift

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Laboratory and Field Tests on Titanium for Oil Field Pump and Valve Parts

CORROSION ◽

10.5006/0010-9312-17.11.16 ◽

1961 ◽

Vol 17 (11) ◽

pp. 16-30

Author(s):

F. W. Jessen ◽

Ricardo J. Molina

Keyword(s):

Crude Oil ◽

Laboratory Tests ◽

Field Tests ◽

Oil Wells ◽

Oil Field ◽

Lower Price ◽

Oil Well ◽

Competitive Disadvantage ◽

Sour Crude ◽

Gas Lift

Abstract Laboratory and field tests are reported for titanium parts for gas lift valves and down-hole oil well pumps. While titanium performed well in the laboratory tests using aerated fluids, and did well in field tests of gas lift wells, similar trials in wells pumping sour crude oil well showed titanium to be inferior to normally used materials. Authors conclude titanium is suitable for use in gas lift valves and could be competitive to presently used materials at a lower price. They conclude titanium is not suitable for use in oil well pumps, but might perform better if hardened. It also is at a competitive disadvantage to commonly used materials costwise. While titanium is cathodic to materials commonly used in oil wells, no marked corrosion was attributed to this property after exposure of coupon sets in a producing well. Titanium was found resistant to abrasion by sand-laden aerated oil well fluids in laboratory tests. 6.3.15, 8.4.3

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Sequential Short-Term Optimization of Gas Lift using Linear Programming: A Case Study of a Mature Oil Field in Russia

Journal of Petroleum Science and Engineering ◽

10.1016/j.petrol.2021.108767 ◽

2021 ◽

pp. 108767

Author(s):

Daein Jeong ◽

Katsuhei Yoshioka ◽

Hoonyoung Jeong ◽

Baehyun Min

Keyword(s):

Linear Programming ◽

Oil Field ◽

Short Term ◽

Gas Lift

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A new experimental method to prevent paraffin - wax formation on the crude oil wells: A field case study in Libya

Hemijska industrija ◽

10.2298/hemind130717040e ◽

2015 ◽

Vol 69 (3) ◽

pp. 269-274 ◽

Cited By ~ 3

Author(s):

Elnori Elhaddad ◽

Alireza Bahadori ◽

Manar Abdel-Raouf ◽

Salaheldin Elkatatny

Keyword(s):

Pour Point ◽

Oil Wells ◽

Fluid Temperature ◽

Gas Field ◽

Ethylene Copolymers ◽

Comb Polymers ◽

Point Temperature ◽

Temperature Range ◽

Gas Lift

Wax formation and deposition is one of the most common problems in oil producing wells. This problem occurs as a result of the reduction of the produced fluid temperature below the wax appearance temperature (range between 46?C and 50?C) and the pour point temperature (range between 42?C and 44?C). In this study, two new methods for preventing wax formation were implemented on three oil wells in Libya, where the surface temperature is, normally, 29?C. In the first method, the gas was injected at a pressure of 83.3 bar and a temperature of 65?C (greater than the pour point temperature) during the gas-lift operation. In the second method, wax inhibitors (Trichloroethylene-xylene (TEX), Ethylene copolymers, and Comb polymers) were injected down the casings together with the gas. Field observations confirmed that by applying these techniques, the production string was kept clean and no wax was formed. The obtained results show that the wax formation could be prevented by both methods.

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