Use of Multiphase Meters in Process Control for Oil Field Well Testing: Performance Enhancement Through GVF Control

First oil production from a deep-water oil field is to be achieved by the installation of an initial development system (IDS). Well testing is required for field development and reservoir management. The well testing system requires high-accuracy oil and water rates to provide the data needed for decision analysis in ongoing drilling programs. The well testing system must also be integrated with other platform operations, such as well cleanup after drilling. We introduce here, the concept of a multiphase meter in series with conventional separation technology for improved process control. This feedback control loop configuration is simulated in MATLAB and shown to extend the capabilities of both technologies. The principle of gas volume fraction control in two-phase separator liquid lines is shown to be supplementary to conventional level control systems for performance enhancement of oil field well testing. Concepts demonstrated here can also be easily applied as retrofits to existing separation facilities, which show accuracy or upset problems.

Download Full-text

Use of Multiphase Meters in Process Control for Oil Field Well Testing: Performance Enhancement Through GVF Control

Engineering Technology Conference on Energy, Parts A and B ◽

10.1115/etce2002/manu-29102 ◽

2002 ◽

Cited By ~ 1

Author(s):

Jack D. Marrelli ◽

Ram S. Mohan ◽

Shoubo Wang ◽

Luis Gomez ◽

Ovadia Shoham

Keyword(s):

Process Control ◽

Performance Enhancement ◽

Oil Field ◽

Testing System ◽

Well Testing ◽

Level Control ◽

Initial Development ◽

Field Development ◽

Water Rates ◽

Compact Size

First oil production from a deep-water oil field is to be achieved by the installation of an Initial Development System (IDS). Well testing is required for field development and reservoir management. The well testing system requires high accuracy oil and water rates to provide the data needed for decision analysis in ongoing drilling programs. The well testing system must also be integrated with other platform operations such as well clean up after drilling. The concept of a certain type of multiphase meter in a feedback control loop with conventional separation technology for process control is simulated to extend the capabilities of both technologies. The principle of GVF control as a supplementary to level control system has been developed for performance enhancement of oil field well testing. Concepts demonstrated here can also be easily applied as retro-fits to existing separation facilities which show accuracy or upset problems because of the simplicity and compact size of the additional multiphase meter component and non-disruptive supplementary integration with existing level control systems.

Download Full-text

The Selection and Optimum Well Testing Practices to Achieve Zero Flaring & Venting in Malaysian Water for a Petronas Field Development

10.2118/207618-ms ◽

2021 ◽

Author(s):

Adhi Naharindra ◽

Zalina Ali ◽

Nik Fazril Ain Sapi’an ◽

Latief Riyanto ◽

Fuziana Tusimin ◽

...

Keyword(s):

Environmental Impact ◽

Oil And Gas ◽

Oil Field ◽

Testing System ◽

Well Testing ◽

Well Test ◽

Flow Lines ◽

Field Development ◽

Well Completion ◽

Production Facilities

Abstract Increased HSE concerns and global economic efficiency from well testing activities especially on its environmental impact have left several oil and gas industries’ facing critical challenges to develop and monetize oil reserves. Some of these challenges include handling well effluents from well test unloading operations after well completion with high contaminants such as H2S and CO2 which will exacerbate environmental impact to safety, pollution, and oil spill risks. In addition, mitigation to environmental impact will be constrained to limited deck space and topside loads for offshore wellhead facilities and eventually restricts the footprint of well test unloading equipment. The scope of the paper is to examine the evolution of well deliverability testing from conventional well test facilities’ flaring practices to contemporary smokeless and zero flaring operations applied in a giant sand stones oil field in Malaysian water, which is surrounded by a world class environmentally protected marine and coastal ecosystem. The zero-flaring approach allows a demonstration of the safety & emission reduction, cost saving, technical viability, and economic benefits over traditional flaring techniques for 20 to 30 well testing during the life of field. Previous wells clean up method require flaring of oil and gas before the production facilities and flow lines were operational.commissioned. The application of environment friendly well testing system using the completed flow lines and production facilities enable zero-flaring option to be technically and economically viable. Zero-flaring well testing system provides several attractive benefits, with potential reduction in flaring equivalent of ±1000 barrels of oil, pollution avoidance, 40 - 50% schedule reduction and over 40% reduction in total project costs for the field development..

Download Full-text

Computer Simulation and Comparison of the Efficiency of Conventional, Polymer and Hydrogel Waterflooding of Inhomogeneous Oil Reservoirs

Eurasian Chemico-Technological Journal ◽

10.18321/ectj680 ◽

2017 ◽

Vol 19 (4) ◽

pp. 323 ◽

Cited By ~ 1

Author(s):

A.N. Chekalin ◽

V.M. Konyukhov ◽

I.V. Konyukhov ◽

A.V. Kosterin ◽

S.V. Krasnov

Keyword(s):

Computer Software ◽

Polymer Flooding ◽

Oil Field ◽

Systems Of Nonlinear Equations ◽

Two Phase ◽

Field Development ◽

Oil Displacement ◽

Aqueous Polymer ◽

First Case ◽

Aqueous Polymer Solution

The oil displacement in a layered inhomogeneous reservoir using two types of physical-chemical technologies (polymer flooding and hydrogel flooding) is the subject of this research. In the first case the aqueous polymer solution of the desired concentration is injected into the porous reservoir creating the high-viscous moving fields. Unlike this technology, the hydrogel flooding is characterized by creation and evolution of the moving hydrogel field directly in porous medium in result of chemical reaction between the water solutions of two gel-forming components which one after another are injected into the oil reservoir with given time interruption. The first component is sorbed more intensively and moves slower than the second one, so when it gradually overtakes the first solution, they begin chemically react with creation of hydrogel. Special numerical methods, algorithms and computer software are developed to solve these systems of nonlinear equations, study and compare an efficiency of the oil field development at the different type of waterflooding. It is shown that creations of the moving polymer or hydrogel fields significantly increases the uniformity of oil displacement in all layers of reservoir and improve their basic exploitation parameters due to the cross-flows between layers and creation of the moving structures in the velocity field of two-phase flow. In doing so, hydrogel technology may be much more effectiveness in comparison with polymer flooding.

Download Full-text

THE ROLE OF RESERVOIR SIMULATION IN THE DEVELOPMENT OF THE CHALLIS AND CASSINI FIELDS

The APPEA Journal ◽

10.1071/aj89013 ◽

1990 ◽

Vol 30 (1) ◽

pp. 212

Author(s):

I.G.D. Gorman

Keyword(s):

Water Injection ◽

Oil Field ◽

Production Performance ◽

Analytical Models ◽

Production Test ◽

Well Performance ◽

Initial Development ◽

Field Development ◽

Production Wells ◽

Interference Test

The Challis oil field development was approved in 1987 with marginal reserves (for an isolated offshore project) of 22 MMbbl. The initial development envisaged three subsea production wells connected via a riser to a floating production facility with one water injector also being required to maximise recovery. However, due to additional potential in the vicinity of the field, the production system was designed to accommodate up to 10 production/injection wells.Further appraisal in 1988/1989 doubled the reserves to 43 MMbbl and increased the number of initial production wells to seven from five reservoirs. The appraisal results also confirmed earlier concerns as to the structural complexity of the field. Analytical interpretations of the production tests performed on the wells could not be fully reconciled with the available well log, core and seismic data. Furthermore, the analytical models developed from these interpretations could not fully match the test results.Reservoir simulation was used to resolve, where possible, the discrepancies. Individual reservoir models were calibrated with the production test results and used to quantify the major uncertainties and their potential impact on production performance. The simulation results indicated that water injection may not be required. However, the degree of internal reservoir communication and the extent of the expected aquifer support were identified as the two principal unknowns.Production policy and monitoring procedures were structured to resolve these uncertainties as quickly as possible during the production start-up phase. Comparative forecasts of expected performance were developed for each reservoir with various levels of aquifer support. A surface controlled interference test was designed to investigate the extent of internal reservoir communication in the main reservoir.The success of the interference test and the results of the early well performance have confirmed the simulation predictions. Simulation modelling was successful in quantifying the range of expected pressure response (to production) for each reservoir and was able to quickly confirm the degree of pressure support present in each reservoir.

Download Full-text