Cement Packer - Another Chance for 2nd Hand Late Life Medco E and P Offshore Field

2021 ◽  
Author(s):  
S. E. Andriyanto
Keyword(s):  
Cost Optimization ◽  
Offshore Platforms ◽  
Operational Cost ◽  
Modus Operandi ◽  
Well Production ◽  
Marginal Production ◽  
Service Activity ◽  
Current Production ◽  
Offshore Field ◽  
Gas Supply

South Natuna Sea Block B PSC (Block B PSC) is one of the key player in Indonesia for supplying gas demand to Singapore and Malaysia. After its acquisition in 2016 by Medco Group, the field is expected to have sustainable gas supply for another 8 years. Hence, to support the plan, aggressive drilling and well service campaigns are enforced to meet the production goal. On mature field, Well Service activity is taking an important role in arresting production decline and in adding short marginal production gain from time to time. With typical well on Block B PSC has multi-zone reservoir, the opportunity to increase production rate is available by accessing the unexploited zone, which some are located above the current Production Packer. The challenge is on how to drain these marginal unexploited zones while maintaining low operational cost. Another challenge is Natuna field has unique characterization compared to other field, not only in terms of geographical condition, but also the way the wells are located on unmanned, minimum facility offshore Platforms. This provide another challenge for the modus operandi of Well Service in Block B PSC fields. The paper describes the challenges and learning curve that Medco E&P Offshore has to address by applying cement packer operation to gain well production, the benefit it has compared with other method, and why cement packer is the chosen method by looking from cost optimization, operational limits and technical limits.

Chemical Deliquification of Unconventional Gas Wells

2014 ◽  
Author(s):  
K.. Francis-LaCroix ◽  
D.. Seetaram
Keyword(s):  
Natural Gas ◽  
Best Practice ◽  
Oil And Gas ◽  
Large Deviation ◽  
Cost Effective ◽  
Gas Production ◽  
Lessons Learned ◽  
Offshore Platforms ◽  
Gas Wells ◽  
Current Production

Abstract Trinidad and Tobago offshore platforms have been producing oil and natural gas for over a century. Current production of over 1500 Bcf of natural gas per year (Administration, 2013) is due to extensive reserves in oil and gas. More than eighteen of these wells are high-producing wells, producing in excess of 150 MMcf per day. Due to their large production rates, these wells utilize unconventionally large tubulars 5- and 7-in. Furthermore, as is inherent with producing gas, there are many challenges with the production. One major challenge occurs when wells become liquid loaded. As gas wells age, they produce more liquids, namely brine and condensate. Depending on flow conditions, the produced liquids can accumulate and induce a hydrostatic head pressure that is too high to be overcome by the flowing gas rates. Applying surfactants that generate foam can facilitate the unloading of these wells and restore gas production. Although the foaming process is very cost effective, its application to high-producing gas wells in Trinidad has always been problematic for the following reasons: Some of these producers are horizontal wells, or wells with large deviation angles.They were completed without pre-installed capillary strings.They are completed with large tubing diameters (5.75 in., 7 in.). Recognizing that the above three factors posed challenges to successful foam applications, major emphasis and research was directed toward this endeavor to realize the buried revenue, i.e., the recovery of the well's potential to produce natural gas. This research can also lead to the application of learnings from the first success to develop treatment for additional wells, which translates to a revenue boost to the client and the Trinidad economy. Successful treatments can also be used as correlations to establish an industry best practice for the treatment of similarly completed wells. This paper will highlight the successes realized from the treatment of three wells. It will also highlight the anomalies encountered during the treatment process, as well as the lessons learned from this treatment.

Optimization of a D-CHP System Based on Monthly Power-to-Heat Ratio

2014 ◽  
Author(s):  
Alta Knizley ◽  
Pedro J. Mago ◽  
James Tobermann
Keyword(s):  
Cost Optimization ◽  
Operating Cost ◽  
Cost Savings ◽  
Optimal Operation ◽  
Practical Implementation ◽  
Operational Cost ◽  
Operational Strategies ◽  
Chp System ◽  
Conventional Systems ◽  
The Relationship

In this paper, a combined heat and power (CHP) system utilizing two power generation units operating simultaneously with differing operational strategies (D-CHP) is analyzed on the basis of operational cost savings. An operating cost optimization metric, based on the facility monthly power-to-heat-ratio (PHR), is presented. The PHR is defined as the ratio between the electric load and the thermal load required by the facility. Previous work in this field has suggested that D-CHP system performance may be improved by limiting operation of the system to months in which the PHR is relatively low. The focus of this paper is to illustrate how the facility PHR can be used to determine the potential of a D-CHP system to reduce operational cost. This paper analyzed the relationship between the PHR and the operational cost savings of six different benchmark buildings, including buildings that are traditionally poor candidates for CHP or D-CHP systems, due to high cost of operation as compared with conventional systems with separate heating and power (SHP). Achieving operational costs savings through optimal operation based on monthly PHR for these building types can enhance the practical implementation potential of D-CHP and CHP systems.

Operational cost optimization of a full-scale SWRO system under multi-parameter variable conditions

Desalination ◽  
2015 ◽  
Vol 355 ◽  
pp. 124-140 ◽  
Author(s):  
Aipeng Jiang ◽  
Jian Wang ◽  
Lorenz T. Biegler ◽  
Wen Cheng ◽  
Changxin Xing ◽  
...  
Keyword(s):  
Cost Optimization ◽  
Full Scale ◽  
Operational Cost

Operational Cost Optimization for Cloud Computing Data Centers Using Renewable Energy

2016 ◽  
Vol 10 (4) ◽  
pp. 1447-1458 ◽  
Author(s):  
Shaoming Chen ◽  
Samuel Irving ◽  
Lu Peng
Keyword(s):  
Cloud Computing ◽  
Renewable Energy ◽  
Data Centers ◽  
Cost Optimization ◽  
Operational Cost

Reliability Modelling: Petrobras 2010 Integrated Gas Supply Chain

2010 ◽  
Author(s):  
Denise Faertes ◽  
Leonardo Saker ◽  
Luciana Heil ◽  
Flavia Vieira ◽  
Francisco Risi ◽  
...  
Keyword(s):  
Supply Chain ◽  
Cost Benefit Analysis ◽  
Commodity Prices ◽  
Cost Benefit ◽  
Offshore Platforms ◽  
Reliability Modeling ◽  
Gas Network ◽  
Contingency Plans ◽  
Reliability Performance ◽  
Gas Supply

The purpose of this paper is to present the innovative reliability modeling of Petrobras 2010 integrated gas supply chain. The model represents a challenge in terms of complexity and software robustness. It was jointly developed by PETROBRAS Gas & Power Department and Det Norske Veritas. It was carried out with the objective of evaluating security of supply of 2010 gas network design that was conceived to connect Brazilian Northeast and Southeast regions. To provide best in class analysis, state of the art software was used to quantify the availability and the efficiency of the overall network and its individual components (such as gas processing units, city-gates, compressor stations, pipelines). The study requests, as input, a lot of information, that should be provided from different sectors of Petrobras, since it is supposed to depict reliability performance of all gas supply chain players. Information such as 2010 design configurations, gas offer and demand profiles, shedding priority, pressure delivery conditions, supply contract and associated penalties, commodity prices, etc., should be raised and addressed. More than twelve processing plants were modeled, in a detailed manner, and have their performance indicators compared. Different gas sources were considered in the study, such as offshore platforms, onshore fields, Bolivia pipeline and LNG ships. Detailed failure probability and repair data were addressed. Contingency plans, for each identified scenario, were made, in order to evaluate probable losses that constitute an input for the reliability modeling. Therefore, two additional software’s were used for their validation: - Pipeline studio – TGNET (from Energy Solutions), to check pressure conditions; and an in-house Petrobras software (PLANAGE), used for best gas allocation purposes. Experienced operational team opinion was incorporated on that contingency plans elaboration. This work constitutes a powerful tool for Petrobras planning and optimization of gas supply chain future configurations. The simulation provides propositions for investments prioritization, based on cost benefit analysis, and as a by-product, contingency plans, that were developed, considering different failure scenarios.

scholarly journals From Consumption to Prosumption - Operational Cost Optimization for Refrigeration System With Heat Waste Recovery

2017 ◽  
Vol 50 (1) ◽  
pp. 11257-11262
Author(s):  
Tomasz Minko ◽  
Jesus Lago Garcia ◽  
Jan Dimon Bendtsen ◽  
Rafael Wisniewski ◽  
Roozbeh Izadi-Zamanabadi
Keyword(s):  
Cost Optimization ◽  
Operational Cost ◽  
Refrigeration System ◽  
Waste Recovery

scholarly journals FEATURES OF THE ANALYSIS OF TECHNOLOGICAL PIPELINES FOR THE DEVELOPMENT OF AN OFFSHORE FIELD USING THE CORRELATION OF SEISMIC IMPACT DATA

2021 ◽  
pp. 24-32
Author(s):  
Liudmila V. Muravieva ◽  
◽  
Igor G. Ovchinnikov ◽  
Keyword(s):  
Fuzzy Logic ◽  
Statistical Analysis ◽  
Seismic Event ◽  
Offshore Platforms ◽  
Seismic Sensors ◽  
Seismic Impact ◽  
Event Based ◽  
Impact Data ◽  
Offshore Field ◽  
Statistical Analysis Methods

Seismic sensors are installed on offshore platforms for recording earthquakes. Technological pipelines are being built, to service the operation of the field. This article is devoted to ensuring the safety of technological pipelines. It deals with the analysis of data on a seismic event based on the correlation of the seismic impact recorded on the platform. Since the process pipelines are located near the platform, using statistical analysis methods, correlation analysis of data recorded at a distance of about 200 m and using fuzzy logic methods, we can have an idea of the degree of impact of the earthquake on the surrounding process pipelines.

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