Sand Management Study: Sand Onset Prediction, Sand Production and Sand Control At Well X

Sand management is essential for enhancing the production in oil and gas reservoirs. The critical total drawdown (CTD) is used as a reliable indicator of the onset of sand production; hence, its accurate prediction is very important. There are many published CTD prediction correlations in literature. However, the accuracy of most of these models is questionable. Therefore, further improvement in CTD prediction is needed for more effective and successful sand control. This article presents a robust and accurate fuzzy logic (FL) model for predicting the CTD. Literature on 23 wells of the North Adriatic Sea was used to develop the model. The used data were split into 70% training sets and 30% testing sets. Trend analysis was conducted to verify that the developed model follows the correct physical behavior trends of the input parameters. Some statistical analyses were performed to check the model’s reliability and accuracy as compared to the published correlations. The results demonstrated that the proposed FL model substantially outperforms the current published correlations and shows higher prediction accuracy. These results were verified using the highest correlation coefficient, the lowest average absolute percent relative error (AAPRE), the lowest maximum error (max. AAPRE), the lowest standard deviation (SD), and the lowest root mean square error (RMSE). Results showed that the lowest AAPRE is 8.6%, whereas the highest correlation coefficient is 0.9947. These values of AAPRE (<10%) indicate that the FL model could predicts the CTD more accurately than other published models (>20% AAPRE). Moreover, further analysis indicated the robustness of the FL model, because it follows the trends of all physical parameters affecting the CTD.

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Taming the Monster: Arresting Excessive Sand Production Problem in ARAMU037

10.2118/207095-ms ◽

2021 ◽

Author(s):

Emily Ako ◽

Erasmus Nnanna ◽

Odumodu Somtochukwu ◽

Akinmade Moradeke

Keyword(s):

North Sea ◽

Niger Delta ◽

Best Practice ◽

Integrated Approach ◽

Sand Production ◽

Sand Control ◽

Production Problem ◽

Normal Production ◽

The Way

Abstract Chemical Sand Consolidation (SCON) has been used as a means of downhole sand control in Niger Delta since the early 70s. The countries where SCON has been used include Nigeria (Niger Delta), Gabon (Gamba) and UK (North Sea). SCON provides grain-to-grain cementation and locks formation fines in place through the process of adsorption of the sand grains and subsequent polymerization of the resin at elevated well temperatures. The polymerized resin serves to consolidate the surfaces of the sand grain while retaining permeability through the pore spaces. In a typical Niger Delta asset, over 30% of the wells may be completed with SCON. A high percentage are still producing without failure since installation from1970s. Where the original SCON jobs have failed, re-consolidation has also been carried out successfully. Chemical Sand Consolidation development has evolved over the years from: Eposand 112A and B, Eposand 212A and B, Wellfix 2000, Wellfix 3000, Sandstop (resin based), Sandtrap 225, 350 & 500 (resin based) and lately Sandtrap 225,350, 500 (solvent based) and Sandtrap ABC (aqueous based). There have been mixed results experienced with the deployment of either of the latest recipes of SCON. This was due to the fact that the conventional deployment work procedure was followed with the tendency for one-size-fits-all approach to the treatment. This paper details the challenges faced with sand production in ARAMU037, the previous interventions and how an integrated approach to the design and delivery of the most recent intervention restored the way to normal production. The well has now produced for about 2 years with minimal interruption with the activity paying out in less than 6 months. The paper also recommends the best practice for remedial sand control especially for wells in mature assets.

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Sand Production in Ultra-Weak Sandstones: Is Sand Control Absolutely Necessary?

10.2118/39042-ms ◽

1997 ◽

Cited By ~ 4

Author(s):

J. Tronvoll ◽

E. Papamichos ◽

A. Skjaerstein ◽

F. Sanfilippo

Keyword(s):

Sand Production ◽

Sand Control

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A geomechanical approach for sanding risk assessment applied to three field cases for completion optimisation

The APPEA Journal ◽

10.1071/aj09040 ◽

2010 ◽

Vol 50 (1) ◽

pp. 623 ◽

Cited By ~ 1

Author(s):

Khalil Rahman ◽

Abbas Khaksar ◽

Toby Kayes

Keyword(s):

Decision Making ◽

Petroleum Industry ◽

Cost Effective ◽

Development Planning ◽

Control Measures ◽

Sand Production ◽

Field Development ◽

Well Completion ◽

Sand Control ◽

Production Prediction

Mitigation of sand production is increasingly becoming an important and challenging issue in the petroleum industry. This is because the increasing demand for oil and gas resources is forcing the industry to expand its production operations in more challenging unconsolidated reservoir rocks and depleted sandstones with more complex well completion architecture. A sand production prediction study is now often an integral part of an overall field development planning study to see if and when sand production will be an issue over the life of the field. The appropriate type of sand control measures and a cost-effective sand management strategy are adopted for the field depending on timing and the severity of predicted sand production. This paper presents a geomechanical modelling approach that integrates production or flow tests history with information from drilling data, well logs and rock mechanics tests. The approach has been applied to three fields in the Australasia region, all with different geological settings. The studies resulted in recommendations for three different well completion and sand control approaches. This highlights that there is no unique solution for sand production problems, and that a robust geomechanical model is capable of finding a field-specific solution considering in-situ stresses, rock strength, well trajectory, reservoir depletion, drawdown and perforation strategy. The approach results in cost-effective decision making for appropriate well/perforation trajectory, completion type (e.g. cased hole, openhole or liner completion), drawdown control or delayed sand control installation. This type of timely decision making often turns what may be perceived as an economically marginal field development scenario into a profitable project. This paper presents three case studies to provide well engineers with guidelines to understanding the principles and overall workflow involved in sand production prediction and minimisation of sand production risk by optimising completion type.

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Implications of accurate geomechanical modelling and systematic core testing for sanding evaluation and sand control decisions – a case study from Perth Basin

The APPEA Journal ◽

10.1071/aj19172 ◽

2020 ◽

Vol 60 (1) ◽

pp. 267

Author(s):

Sadegh Asadi ◽

Abbas Khaksar ◽

Mark Fabian ◽

Roger Xiang ◽

David N. Dewhurst ◽

...

Keyword(s):

Management Strategies ◽

Mechanical Tests ◽

Well Test ◽

Sand Production ◽

Gas Field ◽

Stress Regime ◽

Full Field ◽

Field Development ◽

Sand Control ◽

Rock Mechanical Properties

Accurate knowledge of in-situ stresses and rock mechanical properties are required for a reliable sanding risk evaluation. This paper shows an example, from the Waitsia Gas Field in the northern Perth Basin, where a robust well centric geomechanical model is calibrated with field data and laboratory rock mechanical tests. The analysis revealed subtle variations from the regional stress regime for the target reservoir with significant implications for sanding tendency and sand management strategies. An initial evaluation using a non-calibrated stress model indicated low sanding risks under both initial and depleted pressure conditions. However, the revised sanding evaluation calibrated with well test observations indicated considerable sanding risk after 500 psi of pressure depletion. The sanding rate is expected to increase with further depletion, requiring well intervention for existing producers and active sand control for newly drilled wells that are cased and perforated. This analysis indicated negligible field life sanding risk for vertical and low-angle wells if completed open hole. The results are used for sand management in existing wells and completion decisions for future wells. A combination of passive surface handling and downhole sand control methods are considered on a well-by-well basis. Existing producers are currently monitored for sand production using acoustic detectors. For full field development, sand catchers will also be installed as required to ensure sand production is quantified and managed.

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Addressing sand production challenges — an integrated research approach

The APPEA Journal ◽

10.1071/aj14080 ◽

2015 ◽

Vol 55 (2) ◽

pp. 445

Author(s):

Seng Lim ◽

Bailin Wu ◽

Xavier Choi ◽

Chong Yau Wong ◽

Bahrom Madon ◽

...

Keyword(s):

Research Methodology ◽

Management Strategy ◽

Critical Issue ◽

Production Equipment ◽

Gas Production ◽

Research Approach ◽

Sand Production ◽

Integrated Research ◽

Sand Control ◽

Unconventional Resource

Sand production may be induced by many factors, such as reservoir pressure depletion, excessive draw-down pressure and water-cut. When transported from the formation, the sand particles can cause serious damage to completion and topside assets, impacting the overall productivity and safety of the operating wells. The sand management strategy for a particular field requires careful planning, evaluation and implementation to ensure effective and safe well productivity. The associated CAPEX and OPEX implications and risks can be high if the sanding problem is not managed carefully. This requires a good understanding of field-specific sanding problems. PETRONAS and CSIRO have collaborated on an integrated research program to provide a better understanding of the critical issue affecting sand production and develop associated predictive tools. This involved a multidisciplinary team from geomechanics, fluid mechanics and mathematics to examine the entire sand production process from sand generation, control and transportation to ensure an optimum sand management strategy. This extended abstract provides an overview of the research methodology based on experimental and numerical modelling techniques supported by field information. The study focuses on sand production behaviour, as well as failure of down-hole sand control equipment. The research led to better prediction and quantification of the sand production propensity, as well as erosion severity on critical production equipment. Insights and operational guidelines were also established to assist production and facility engineers in managing sand production challenges. This integrated research methodology would be applicable to unconventional resource areas, such as coal seam gas or shale gas production.

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Numerical Investigation of Sand-Screen Performance in the Presence of Adhesive Effects for Enhanced Sand Control

SPE Journal ◽

10.2118/195686-pa ◽

2019 ◽

Vol 24 (05) ◽

pp. 2195-2208 ◽

Cited By ~ 2

Author(s):

Siti Nur Shaffee ◽

Paul F. Luckham ◽

Omar K. Matar ◽

Aditya Karnik ◽

Mohd Shahrul Zamberi

Keyword(s):

Management Practices ◽

Oil And Gas ◽

Voronoi Tessellation ◽

Oil And Gas Industry ◽

Solid Particles ◽

Particle Adhesion ◽

Sand Production ◽

Gas Industry ◽

Particle Filtration ◽

Sand Control

Summary In many industrial processes, an effective particle–filtration system is essential for removing unwanted solids. The oil and gas industry has explored various technologies to control and manage excessive sand production, such as by installing sand screens or injecting consolidation chemicals in sand–prone wells as part of sand–management practices. However, for an unconsolidated sandstone formation, the selection and design of effective sand control remains a challenge. In recent years, the use of a computational technique known as the discrete–element method (DEM) has been explored to gain insight into the various parameters affecting sand–screen–retention behavior and the optimization of various types of sand screens (Mondal et al. 2011, 2012, 2016; Feng et al. 2012; Wu et al. 2016). In this paper, we investigate the effectiveness of particle filtration using a fully coupled computational–fluid–dynamics (CFD)/DEM approach featuring polydispersed, adhesive solid particles. We found that an increase in particle adhesion reduces the amount of solid in the liquid filtrate that passes through the opening of a wire–wrapped screen, and that a solid pack of particle agglomerates is formed over the screen with time. We also determined that increasing particle adhesion gives rise to a decrease in packing density and a diminished pressure drop across the solid pack covering the screen. This finding is further supported by a Voronoi tessellation analysis, which reveals an increase in porosity of the solid pack with elevated particle adhesion. The results of this study demonstrate that increasing the level of particle agglomeration, such as by using an adhesion–promoting chemical additive, has beneficial effects on particle filtration. An important application of these findings is the design and optimization of sand–control processes for a hydrocarbon well with excessive sand production, which is a major challenge in the oil and gas industry.

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Sand Production Assessment & Sand Control Selection for Steam Flood in South Oman

10.2118/193777-ms ◽

2018 ◽

Author(s):

Wafa Al Shizawi ◽

Ruqaiya Al Zadjali ◽

Sandeep Mahajan ◽

Lars Bellmann

Keyword(s):

Sand Production ◽

Control Selection ◽

Sand Control ◽

Steam Flood ◽

Selection For

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

10.2118/200988-ms ◽

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.

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Evaluation of Latest Technological Advances in Sand Control Completions: A Case Study

10.2118/208447-ms ◽

2021 ◽

Author(s):

Rishabh Bharadwaj ◽

Manish Kumar ◽

Shashwat Harsh ◽

Deepak Mishra

Keyword(s):

Oil And Gas ◽

Control Method ◽

Control Mechanisms ◽

Sand Production ◽

Production Rates ◽

Reservoir Properties ◽

Water Contact ◽

Technological Advances ◽

Sand Control ◽

Gravel Pack

Abstract Sand control poses huge financial loses during production operations particularly in mature fields. It hinders economic oil production rates as well as damages downhole and surface equipment due to its abrasive action. Excessive sand production rates can plug the wellhead, flow lines, and separators which can result in detrimental well control situations. This paper will provide a comparative study on various sand control mechanisms by reviewing the latest advancements in sand management techniques. This study evaluates the performance of through-tubing sand screens, internal gravel pack, cased hole expandable sand screen, modular gravel pack system, openhole standalone screen, multi-zone single trip gravel pack, slim gravel pack, and chemical sand consolidation mechanisms. Various field examples from Niger-Delta, Mahakam oil and gas block, and offshore Malaysia are examined to gain an insight about the application of aforementioned sand control methods for different type of reservoirs. This study enables the operator to tackle the sand production problem according to the well construction changes during the life cycle of a well. The internal gravel pack completion system delivers a prolonged plateau production regime in shallow depths. In high drawdown conditions, chemical sand consolidation completion incurs early water breakthrough and elevated sand production. Chemical sand consolidation technique yields better results in deeper formations and its placement can be improvised by implementing coiled tubing and diversion techniques for multi-stage treatments. Depending on the well inclination, gas-water contact, producing zone type and thickness, well age, and economy, the completion types out of modular gravel pack, openhole standalone screen, slim gravel pack, and through tubing sand screen is recommended accordingly. Acquiring offset data, well log analysis, particle size distribution and performing pressure tests will improve the data quality of the obtained reservoir properties. This will further help in the selection of the most suitable sand control method for the target reservoir.

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