A Study of Coupling Surface Network to Reservoir Simulation Model in a Large Middle East Field

Almutairi, Saad; Hayder, Ehtesham M.; Alshammari, Ahmad S.; Al-Jama, Nayif; Múñoz, Alberto

doi:10.2523/127976-ms

Cited by 5 publications

(3 citation statements)

References 0 publications

Supporting

Mentioning

Contrasting

Order By: Relevance

“…Dempsey et al 14 were the first to study the coupling of gas reservoir flow simulation and surface system simulation. Startzman et al, 15 Trick et al, 16 Litvak and Darlow, 17 Coats et al, 18 Al-Mutairi et al, 19 and Gu¨yagu¨ler et al 20 proposed different reservoir/wellbore/surface system integration models. However, all the models were developed for conventional gas reservoirs, and therefore, they cannot be applied to an unconventional gas reservoir like a CBM well because of the adsorbed state and drainage gas recovery mechanism of CBM.…”

Section: Production System Simulation Modelsmentioning

confidence: 99%

See 1 more Smart Citation

Optimization design of coalbed methane pipeline network–coupled wellbore/reservoir simulation

Zhou

Liang

Deng

et al. 2017

Advances in Mechanical Engineering

View full text Add to dashboard Cite

The extraction of coalbed methane, unlike that of conventional gas resources, is characterized by low gas production and low pressure. The traditional optimization methods only focus on the surface system, ignoring the relationship between the surface system and coalbed methane production. Furthermore, the pipeline network suggested by these methods is based on the given productivity of a single well. This article proposes a surface system layout optimization architecture coupled with a production system simulation that considers the profit made in the production cycle as the objective function. Using case studies, we show that the proposed optimization method improves the gas production rate by about 10.9% and increases the profit by 2 million dollars. When the results are analyzed under different network topologies, the tree network emerges as the cheapest and the star network emerges as the most expensive in terms of ground investment. However, when considering productivity and profit, the star network is the best and the tree network is the worst, while the concatenated network is intermediate. The results show that the structure of the surface network has a considerable influence on the coalbed methane reservoirs. Therefore, this article recommends the star structure arrangement for the coalbed methane surface system.

show abstract

Section: Production System Simulation Modelsmentioning

confidence: 99%

“…A pipeline network system consists of n nodes and m sections. The node matrix equation formed by the n continuity equations can be written as equation (19). The relationship between the pressure loss and the section flow rate can be expressed as equation (20).…”

Section: Surface Pipeline Network Modelmentioning

confidence: 99%

Optimization design of coalbed methane pipeline network–coupled wellbore/reservoir simulation

Zhou

Liang

Deng

et al. 2017

Advances in Mechanical Engineering

View full text Add to dashboard Cite

show abstract

“…A detailed description has been previously described 3,5 , but we will present a brief description in this paper. A detailed description has been previously described 3,5 , but we will present a brief description in this paper.…”

Section: Coupled Simulation Workflowmentioning

confidence: 99%

Facilities Planning Using Coupled Surface and Reservoir Simulation Models

Hayder

Munoz²,

Al-Shammari

2011

All Days

Self Cite

View full text Add to dashboard Cite

TX 75083-3836, U.S.A., fax 01-972-952-9435. AbstractWe will discuss issues in developing a production-injection surface facility model to optimize both oil production and water injection strategy in a mature giant oil field. Surface facility modeling was done using commercially available software, which was coupled to Saudi Aramco's in-house reservoir simulator POWERS 1 . Multiple integrated strategies for analyzing production can be considered with such models. In this paper, we evaluate a facility optimization perspective where many wells are rerouted between multiple gas-oil separation plants (GOSPs) to maintain adequate reservoir pressure to deliver required oil production volumes at the lowest operating cost. We also consider cases where the objective is to evaluate injection allocation strategies, which honors surface constraints, especially surface flow lines' maximum operating pressure restrictions. Results presented in this paper include a subsurface reservoir coupled surface facility model where proposed strategies are designed to reroute wells from five existing GOSPs producing at high water cuts to two remaining GOSPs for production consolidation. Such strategy allows for an immediate cost savings, since it reduces the number of plants while at the same time producing the required volumes of oil, at reduced water cut, while at the same time maintaining reservoir sweep and recovery since wells which otherwise might have been shut-in are kept on active production. Simultaneously with the option of optimizing oil production, rerouting offers the opportunity to examine water disposal strategies since water can be injected near locations where there might be either a need for additional sweep or simply for reservoir pressure control and redistribution without compromising overall oil production.We built a surface facility model consisting of five active GOSPs with a few hundred producers and injector (disposal) wells. The surface model is coupled to an over a million-cell reservoir model, containing a sub-set of all the wells available in the POWERS simulation model. Previous work had relied on describing exclusively the production system, leaving the injection system to be handled by POWERS' well management rules and not subject to optimization or reconfiguration based on reservoir strategies. In this study, both the production and injection model have been constructed and calibrated using the latest available field data and history matched to field performance current at the time of calibration. Model calibration has been assisted by using automated scripts that transfer the relevant production and technical data from a corporate database to the individual model well files and which provide initial estimates for appropriate calibration parameter, such as productivity index, gradient curve matching or reservoir pressure at the time of a rate test, to current or historical field data. Those initial matches are later reviewed and validated on a well by well basis prior to use for prediction runs.

show abstract

Evaluation of Explicit Coupling Between Reservoir Simulators and Production System

Filho

Schiozer

2014

Journal of Energy Resources Technology

View full text Add to dashboard Cite

In recent years, the oil industry has used various methodologies to solve numerical coupling of reservoirs and production systems to properly model complex projects needing an integrated solution of computational models that represent the fluid flow through the reservoir up to the surface. We present a study of explicit coupling methodology testing the production system on common operating conditions, verifying the benefits and quantifying limitations of explicit methodology, due to numerical stability errors reported in literature.

show abstract

A Study of Coupling Surface Network to Reservoir Simulation Model in a Large Middle East Field

Cited by 5 publications

References 0 publications

Optimization design of coalbed methane pipeline network–coupled wellbore/reservoir simulation

Optimization design of coalbed methane pipeline network–coupled wellbore/reservoir simulation

Facilities Planning Using Coupled Surface and Reservoir Simulation Models

Evaluation of Explicit Coupling Between Reservoir Simulators and Production System

Contact Info

Product

Resources

About