Enhancing Gas Injection Compressors Performance by Lateral Thinking Resulting in 0.62 Million Barrels Oil Per Year Additional Production Capacity at Zero Cost

2021 ◽  
Author(s):  
Muhammad Arif ◽  
Abdulla Mohammed Al Jneibi
Keyword(s):  
High Pressures ◽  
Gas Injection ◽  
Production Capacity ◽  
Oil Production ◽  
Oil Field ◽  
Effective Capacity ◽  
Set Point ◽  
Associated Gas ◽  
Lateral Thinking ◽  
Operational Excellence

Abstract The Fourth Industrial Revolution (4.0) in Oil & Gas Industry creates a dynamic landscape where Operational Excellence (OE) strives for stability, quality, and efficiency while continuing to serve an increasingly demanding customer. Operational excellence is a journey, not a sole destination. Abu Dhabi National Oil Company (ADNOC) Onshore, one of the South East Fields, oil production capacity was constrained due to the limitation of associated gas handling capacity of the compressors. Gas flow towards the compressor was not steady due to natural flowing wells non-steady behavior and this disturbance cannot be removed from the system. The situation was quite complicated. In order to produce oil, associated gas must be handled to avoid flaring. It was more than a challenge to increase the compressors effective capacity without any hardware modification. Since flaring is not permitted in ADNOC and running of huge capacity standby compressor was not economically viable, therefore, Field Operations by lateral thinking transformed this challenging situation into an opportunity and enhanced compressor effective capacity by expanding its operating envelope to handle additional gas. One innovative solution proposed by Field Operations was to expand the pressure-operating envelope of the machine to withstand high pressures without tripping. The idea was to increase the machine throughput by elevating the machine high-pressure trip set point along with Pressure Safety Valve (PSV) set point elevation. This submission shares success story of an oil field Operations in house efforts to enhance the gas injection compressor effective capacity by 600 MSCFD which subsequently increased the oil production capacity by 1700 bopd or 0.62 million barrels oil per year by Operational Excellence. Operational Excellence played its role with a value improvement objective. Rather than replacing successful practices and programs, Operational Excellence knitted them into a larger, fully integrated tapestry woven to increase value produced within the overall business strategy which is very evident in this scenario. This case study is blend of Operations Excellence and innovation representing Management support to employee to solve complex problems. Such support is always beneficial for the company and employee. Management of change process for followed to study, analyze and implement the idea.

THE DEVELOPMENT OF THE TIRRAWARRA OIL AND GAS FIELD

1984 ◽  
Vol 24 (1) ◽  
pp. 278
Author(s):  
H. T. Pecanek ◽  
I. M. Paton
Keyword(s):  
Carbon Dioxide ◽  
Oil And Gas ◽  
Gas Injection ◽  
Oil Field ◽  
Oil Reservoir ◽  
Gas Reservoirs ◽  
Gas Field ◽  
Associated Gas ◽  
Oil And Gas Field ◽  
Cooper Basin

The Tirrawarra Oil and Gas Field, discovered in 1970 in the South Australian portion of the Cooper Basin, is the largest onshore Permian oil field in Australia. Development began in 1981 as part of the $1400 million Cooper Basin Liquids ProjectThe field is contained within a broad anticline bisected by a north-south sealing normal fault. This fault divides the Tirrawarra oil reservoir into the Western and Main oil fields. Thirty-four wells have been drilled, intersecting ten Patchawarra Formation sandstone gas reservoirs and the Tirrawarra Sandstone oil reservoir. Development drilling discovered three further sandstone gas reservoirs in the Toolachee Formation.The development plan was based on a seven-spot pattern to allow for enhanced oil recovery by miscible gas drive. The target rates were 5400 barrels of oil (860 kilolitres) per day with 13 million ft3 (0.37 million m3) per day of associated gas and 70 million ft3 (2 million m') per day of wet, non-associated gas. Evaluation of early production tests showed rapid decline. The 100 ft (30 m) thick, low-permeability Tirrawarra oil reservoir was interpreted as an ideal reservoir for fracture treatment and as a result all oil wells have been successfully stimulated, with significant improvement in well production rates.The oil is highly volatile but miscibility with carbon dioxide has been proven possible by laboratory tests, even though the reservoir temperature is 285°F (140°C). Pilot gas injection will assess the feasibility of a larger-scale field-wide pressure maintenance scheme using miscible gas. Riot gas injection wells will use Tirrawarra Field Patchawarra Formation separator gas to defer higher infrastructure costs associated with the alternative option of piping carbon dioxide from Moomba, the nearest source.

‘Zero Routine Flaring by 2030': a new global industry standard

2018 ◽  
Vol 58 (2) ◽  
pp. 533
Author(s):  
Jane Cutler ◽  
Bjorn Hamso ◽  
Francisco Sucre
Keyword(s):  
World Bank ◽  
Good Practice ◽  
Oil Production ◽  
Oil Field ◽  
Positive Contribution ◽  
Associated Gas ◽  
Oil Companies ◽  
Gas Flaring ◽  
Global Industry ◽  
Industry Standard

The World Bank-introduced ‘Zero Routine Flaring by 2030’ (ZRF) Initiative is well on its way to establishing a new global industry standard; one that is very important if governments and industry are to make significant strides to help mitigate climate change. Launched in 2015 by the UN Secretary-General and World Bank President, ZRF commits governments and oil companies to (a) not routinely flare associated gas in new oil field developments, and (b) to end routine flaring at existing (legacy) fields by 2030. (Routine flaring is defined as flaring during normal oil production operations in the absence of sufficient facilities or amenable geology to re-inject the produced gas, utilise it on-site, or dispatch it to a market. The ZRF Initiative clearly states that venting is also not an acceptable substitute for flaring.) A review of the governments and companies that have already endorsed ZRF reveals that many of the major producers recognise the value of making a public commitment and working to end a 150-year-old industry practice. There are now over 70 endorsers, but more governments and companies must join the global effort if there is to be real progress and establishment of a de facto industry standard. Those that have endorsed the ZRF Initiative say it has other tangible benefits. For example, the many international oil companies that already have a no-flaring policy for new oil field developments consider the Initiative a positive contribution because it will level the playing field – other companies would adopt the same good practice and governments would require it. So, the Initiative also reduces regulatory uncertainty and risk. To achieve ZRF on a global scale, collaborative action such as through the Global Gas Flaring Reduction Partnership (GGFR) – a public-private initiative comprising international and national oil companies, national and regional governments, and international institutions – will be required. GGFR is focused on increasing the use of natural gas associated with oil production by helping remove technical and regulatory barriers to flaring reduction, conducting research, disseminating best practices, and developing country-specific gas flaring reduction programs. GGFR is also focused on helping develop financing tools for flare-out projects, such as a new program with the Global Infrastructure Facility (GIF) to fund feasibility studies of solutions to monetize flared or vented gas from onshore and offshore oil production facilities.

Selection of effective wax (deposition) inhibitors to oil production and transportation at the Kondinskoye oil field

2020 ◽  
pp. 120-127
Author(s):  
E. N. Skvortsova ◽  
O. P. Deryugina
Keyword(s):  
Laboratory Tests ◽  
Initial Dosage ◽  
Oil Production ◽  
Oil Field ◽  
Transport Systems ◽  
Asphaltene Precipitation ◽  
Wax Deposition ◽  
Selection Of ◽  
Pilot Tests

The article discusses the results of a study on the selection of wax inhibitors that can be used at the Kondinskoye oil field during transportation and dehydration of the emulsion.Asphaltene precipitation is one of the most serious issues in oil production. The experiment was conducted in order to select the most effective wax inhibitors. We have carried out laboratory tests to choose the most effective wax inhibitor in the conditions of oil production, collection, preparation and external transport systems at the Kondinskoye oil field. Based on the data obtained, wax inhibitor-2, wax inhibitor-4, and wax inhibitor-6 have shown the best results in ensuring the efficiency of inhibition, which should be at least 70 %, and, therefore, they can be allowed to pilot tests. The recommended initial dosage of inhibitors according to the results obtained during pilot tests should be at least 500 g/t of oil.

Study and Comparison of Vibration-Based Intrusive and Non-Intrusive Sand Monitoring System

2013 ◽  
Vol 701 ◽  
pp. 440-444
Author(s):  
Gang Liu ◽  
Peng Tao Liu ◽  
Bao Sheng He
Keyword(s):  
Real Time ◽  
Monitoring System ◽  
Oil Production ◽  
Oil Wells ◽  
Oil Field ◽  
Sand Production ◽  
The Status

Sand production is a serious problem during the exploitation of oil wells, and people put forward the concept of limited sand to alleviate this problem. Oil production with limited sanding is an efficient mod of production. In order to complete limited sand exploitation, improve the productivity of oil wells, a real-time sand monitoring system is needed to monitor the status of wells production. Besides acoustic sand monitoring and erosion-based sand monitoring, a vibration-based sand monitoring system with two installing styles is proposed recently. The paper points out the relationships between sand monitoring signals collected under intrusive and non-intrusive installing styles and sanding parameters, which lays a good foundation for further study and actual sand monitoring in oil field.

Evaluation of CO2 Gas Injection For Major Oil Production Fields in Malaysia - Experimental Approach Case Study: Dulang Field

2001 ◽  
Author(s):  
Zahidah Md. Zain ◽  
Nor Idah Kechut ◽  
Ganesan Nadeson ◽  
Noraini Ahmad ◽  
D.M. Anwar Raja
Keyword(s):  
Experimental Approach ◽  
Gas Injection ◽  
Oil Production ◽  
Co2 Gas

scholarly journals Study on aerobic corrosion characteristics of gas injection pipe wall in oil field under dry / wet interaction condition

2021 ◽  
Vol 647 ◽  
pp. 012076
Author(s):  
T. Cheng ◽  
Y.B. Dang ◽  
F.T. Hu ◽  
Z.W. Jia ◽  
Z. Niu ◽  
...  
Keyword(s):  
Pipe Wall ◽  
Gas Injection ◽  
Oil Field

Increasing Wells Lifetime by Using PAR VALVE to Overcome Sand Settling Problems at Pertamina EP Asset 1 Field Jambi

2021 ◽  
Author(s):  
A. S. Ramadhan
Keyword(s):  
Oil Production ◽  
Oil Field ◽  
Average Lifetime ◽  
Sand Production ◽  
Maintenance And Repair ◽  
Engine Maintenance

In the Jambi oil field, sand production can create unattainable production targets and short-lived well lifetime. One function of the Jambi Engineering and Planning Field is to look for solutions to these problems, such as the installation of progressive cavity pumps (PCP) into wells. Although successful, a problem that often arises in PCP wells is sand settling when the PCP is off, for example during electric trips, engine maintenance and repair of flowlines. This settling can lead to a stuck PCP. A recent solution has been to install a Pressure Actuated Relief (PAR) valve, where the tool directs sand deposits out of the tubing to the annulus so that it does not enter the pump. Installation of this tool has increased the average lifetime of sandy wells from 2 months to 6 months, and has increased oil production in these wells by up to 47%.This paper will discuss the successful installation of a PAR Valve into well KTT-08 in the Jambi Field.

Pilot Project Evaluating WAG Efficiency for Carbonate Reservoir in Eastern Siberia

2021 ◽  
Author(s):  
Valentina Zharko ◽  
Dmitriy Burdakov
Keyword(s):  
Oil Recovery ◽  
Gas Injection ◽  
Oil Production ◽  
Pilot Project ◽  
Carbonate Reservoir ◽  
Recovery Factor ◽  
Eastern Siberia ◽  
Water Cut ◽  
Wag Injection ◽  
Injection Rates

Abstract The paper presents the results of a pilot project implementing WAG injection at the oilfield with carbonate reservoir, characterized by low efficiency of traditional waterflooding. The objective of the pilot project was to evaluate the efficiency of this enhanced oil recovery method for conditions of the specific oil field. For the initial introduction of WAG, an area of the reservoir with minimal potential risks has been identified. During the test injections of water and gas, production parameters were monitored, including the oil production rates of the reacting wells and the water and gas injection rates of injection wells, the change in the density and composition of the produced fluids. With first positive results, the pilot area of the reservoir was expanded. In accordance with the responses of the producing wells to the injection of displacing agents, the injection rates were adjusted, and the production intensified, with the aim of maximizing the effect of WAG. The results obtained in practice were reproduced in the simulation model sector in order to obtain a project curve characterizing an increase in oil recovery due to water-alternating gas injection. Practical results obtained during pilot testing of the technology show that the injection of gas and water alternately can reduce the water cut of the reacting wells and increase overall oil production, providing more efficient displacement compared to traditional waterflooding. The use of WAG after the waterflooding provides an increase in oil recovery and a decrease in residual oil saturation. The water cut of the produced liquid decreased from 98% to 80%, an increase in oil production rate of 100 tons/day was obtained. The increase in the oil recovery factor is estimated at approximately 7.5% at gas injection of 1.5 hydrocarbon pore volumes. Based on the received results, the displacement characteristic was constructed. Methods for monitoring the effectiveness of WAG have been determined, and studies are planned to be carried out when designing a full-scale WAG project at the field. This project is the first pilot project in Russia implementing WAG injection in a field with a carbonate reservoir. During the pilot project, the technical feasibility of implementing this EOR method was confirmed, as well as its efficiency in terms of increasing the oil recovery factor for the conditions of the carbonate reservoir of Eastern Siberia, characterized by high water cut and low values of oil displacement coefficients during waterflooding.

Unlocking By-Passed Oil with Autonomous Inflow Control Devices Through an Integrated Approach

2021 ◽  
Author(s):  
Pawan Agrawal ◽  
Sharifa Yousif ◽  
Ahmed Shokry ◽  
Talha Saqib ◽  
Osama Keshtta ◽  
...  
Keyword(s):  
Continuous Production ◽  
Oil Production ◽  
Gas Production ◽  
Oil Field ◽  
Production Performance ◽  
Fluid Distribution ◽  
Flow Profile ◽  
Horizontal Drain ◽  
Control Devices

Abstract In a giant offshore UAE carbonate oil field, challenges related to advanced maturity, presence of a huge gas-cap and reservoir heterogeneities have impacted production performance. More than 30% of oil producers are closed due to gas front advance and this percentage is increasing with time. The viability of future developments is highly impacted by lower completion design and ways to limit gas breakthrough. Autonomous inflow-control devices (AICD's) are seen as a viable lower completion method to mitigate gas production while allowing oil production, but their effect on pressure drawdown must be carefully accounted for, in a context of particularly high export pressure. A first AICD completion was tested in 2020, after a careful selection amongst high-GOR wells and a diagnosis of underlying gas production mechanisms. The selected pilot is an open-hole horizontal drain closed due to high GOR. Its production profile was investigated through a baseline production log. Several AICD designs were simulated using a nodal analysis model to account for the export pressure. Reservoir simulation was used to evaluate the long-term performance of short-listed scenarios. The integrated process involved all disciplines, from geology, reservoir engineering, petrophysics, to petroleum and completion engineering. In the finally selected design, only the high-permeability heel part of the horizontal drain was covered by AICDs, whereas the rest was completed with pre-perforated liner intervals, separated with swell packers. It was considered that a balance between gas isolation and pressure draw-down reduction had to be found to ensure production viability for such pilot evaluation. Subsequent to the re-completion, the well could be produced at low GOR, and a second production log confirmed the effectiveness of AICDs in isolating free gas production, while enhancing healthy oil production from the deeper part of the drain. Continuous production monitoring, and other flow profile surveys, will complete the evaluation of AICD effectiveness and its adaptability to evolving pressure and fluid distribution within the reservoir. Several lessons will be learnt from this first AICD pilot, particularly related to the criticality of fully integrated subsurface understanding, evaluation, and completion design studies. The use of AICD technology appears promising for retrofit solutions in high-GOR inactive strings, prolonging well life and increasing reserves. Regarding newly drilled wells, dedicated efforts are underway to associate this technology with enhanced reservoir evaluation methods, allowing to directly design the lower completion based on diagnosed reservoir heterogeneities. Reduced export pressure and artificial lift will feature in future field development phases, and offer the flexibility to extend the use of AICD's. The current technology evaluation phases are however crucial in the definition of such technology deployments and the confirmation of their long-term viability.

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