bluuebunny/crossref_metadata_2025_split huggingface dataset:
Sustenance and Management of a Matured Waterflood - A Niger Delta Case Study
Authors: Olayemi Sarah , Ileagu Charles , Opusunju Augusta , Kalio Samuel , Olabisi Akadiri 
Published: February 2011

Abstract
The field started production in 1965, it is structurally complex, comprising of several structural closures contained within three major fault blocks. The flooded reservoir block discussed in this paper came into production in 1965. Rapid pressure decline (55 psi per 1 % of STOIIP produced) was observed in the early production life of the reservoir.
The rapid reservoir pressure decline caused shrinkage losses and expansion of the gas cap; this in turn resulted in production problems. A case for water injection was made & full-scale water injection commenced in 1978 with 3 injection wells taking water from a shallow aquifer through 2 source water wells. In addition to arresting further reservoir pressure decline, the project protects a reservoir production rate of 3.5kbopd and safeguards up to 10 MMstb remaining reserves.
The water injection project like many matured waterflood systems operated under matrix conditions was plagued by frequent loss of injectivity & surface facility integrity issues coupled with the peculiar security situation of the Niger Delta.
This paper describes;
How well & surface challenges with the water injection project have been resolved Continuing operational and performance monitoring methods to sustain and optimally manage the peripheral water injection
The Role of Petroleum Engineering Education in the Enhancement of Oil and Gas Production
Authors: Ogbonna Festus C. , Chukwu Godwin 
Published: February 2011

Abstract
Education is a primary concern of the international oil and gas industry at present (Ronalds, 2002). Quantitative competence is important, but will not likely separate professionals from their fellow competitors. There is a limit to the progress to be made in the petroleum profession based on technical competence alone. This paper investigates and creates a better understanding of those basic elements which must form part of a petroleum engineer's education in the new millennium to enhance production and meet demands. In the backdrop of the identified challenges faced by industry, the elements discussed include critical reasoning, business & uncertainty management, leadership, teamwork skills, ethics and professionalism, the humanities, and communication. These help to understand how the petroleum engineer's education should evolve so as to cope with the changing environment and ensure career success.
This study reveals that the petroleum engineer's soft skills and knowledge of these elements require expansion. Creation of an expanded curriculum is necessary to tap into the subjects that engage the younger generation. Model curricula in selected top petroleum universities are studied to identify areas for emulation and for improvement. Educational models that could help transfer competence to the Third World institutions are proposed.
Use of Critical Multiphase Flow Correlation for Bean Surveillance
Authors: Nnanna Erasmus , Akaeze Raphael , Mbanefo Edith , Opusunju Augusta 
Published: February 2011

ABSTRACT
A simple technique for investigating choke erosion based on critical multiphase flow correlation has been developed. It utilizes the coefficient (C-constant) in the correlation for determining whether the bean is being eroded or plugged. The coefficient remains fairly constant for a given well but only deviates if the bean is being subjected to erosion or plugging or if the well's operating point is in the sub-critical flow region. Bean erosion and plugging were simulated using a surface facility-coupled well model constructed with Prosper software. The model showed that the C-constant decreased when the bean was being eroded and increased when the bean was experiencing plugging. Test performance for cases of bean plugging was not available and therefore, the study focussed on bean erosion alone. Actual production test data were used from different fields where choke erosion has been reported in verifying the concept. The technique was also used to back-calculate the effective bean sizes for the wells with eroded bean. It was evident that the wells have been produced with effective bean sizes outside the desired operating window with the attendant reservoir management consequences.
This paper recommends the use of this technique for verifying production test to ascertain the integrity of the reported bean size for reservoir management. The analysis can also be used to advise on the priority wells for bean box checks/bean change out. It can also be used to expedite calibration of integrated production system models (IPSM) with the right bean sizes.
Pipeline Laser Imaging and Metrology Using Laser Smart Pig
Authors: Ekpemu U. , Aloba S. 
Published: February 2011

Abstract
This paper describes a novel technology at the final development stage using laser optical sensor technology for pipeline inspection. Laser profiling systems have previously been developed for surface applications, but they have not been available for practical subsea use. SLD has worked on several subsea laser profiling technologies and demonstrated the potential of the Laser Smart Pig (LSP1) not only on surface applications but also on underwater applications. This is an offset of the known Magnetic Flux Leakage Inline Inspection tool (MFL-ILI), where the smart pig is used to inspect the pipeline with sensors and records the data for later analysis.
This technology is built on the skills and vast years of experience of the research team in SLD who are developing new formats of Subsea laser dimensional information and imaging systems. The technology uses two lasers and a camera to collect enough data in order to produce a 3D reconstruction of the inside of the pipeline within 1mm resolution. It detects corrosion, erosion and any geometric deformation with a very good accuracy inside the pipeline. This tool can be deployed in pipelines on land, and underwater. With the growing number of pipelines underwater in Nigeria and on surface, accurate dimensional information and images of pipelines which the LSP1 provides, is essential for the early detection of faults which could lead to a shortening of the life of the pipeline.
Integrated Formation Resistivity Forward Modeling; A Case Study Of A Carbonate Reservoir
Authors: Affandi Ridho , Kunto Tri Widyo , Nurali Yusup , Darmawan Ganesha Rinku , Setiawan Adjie 
Published: February 2011

Abstract
Challenging situation happens in development of a carbonate reservoir (Kujung Formation) in ‘X’ Field, East Java, Indonesia, in contrast with overpressure and sloughing shale above it. The presence of sour gas with 7000 ppm of H2S increased the level of complexity in drilling operations. The actual carbonate top formation (Top Kujung Formation) is difficult to be predicted only from seismic data, as in some area of deposition there are development of "reef talus" which could lead to wrong interpretations and premature casing set which could bring unwanted consequences. One well was facing premature casing set, the other well was drill thru the carbonate and facing severe losses and cannot be cured by loss circulation material and cement which increased the drilling cost. Learning from previous drilling operations, a formation Resistivity forward modeling which including real time modeling with Logging While Drilling (LWD) and integrated with rock cutting analysis. Formation Resistivity modeling was developed based on four wells previously drilled in the structure. Two different Resistivity models that might be encountered during drilling and model update during drilling operation is a must to avoid drilling deeper into the carbonate. Upper layer easily recognized using log correlation, followed/calibrated with confirmation from mud logging cutting data by real time correlation and forward modeling with LWD geoVISION Resistivity and Array Resistivity Compensated (GVR-ARC mark of Schlumberger) from 50 - 100 meters from the expected top carbonates. This paper provide detailed method of precise top carbonate determination in this case Top Kujung Formation for the one recently drilled wells in the structure "X", improving zone isolation with precise casing setting depth, integrated with Resistivity forward modeling where this method has been successfully implemented.
Magnetized Water for Improve Sweep Efficiency
Authors: Effiong G. M. , Appah D. , Abbey T. M. 
Published: February 2011

Abstract
Mature oil and gas fields are difficult to rehabilitate effectively because of the economics and declining production. Many fields are abandoned prematurely when their life could be prolonged significantly through application of new technology. Based on this notion, mechanisms of petroleum recovery by magnetized water injection were taken into consideration. Advantages and disadvantages of its injection in the petroleum reservoirs have been reviewed and compared with water flooding. The magnetized water flooding result was remarkable when compared to ordinary water and saline water flooding result.
During the course of the study, a mathematical model of the forces involved in magnetized water flooding was developed and the result of the model was validated in the laboratory experimentally. Based on the extensive studies it was observe that the laboratory result was in agreement with the mathematical model developed. From the result gotten, it is strongly convinced that the technique of using magnetized water to flood pressure depleted reservoirs hold promise in the future. If adequately applied can recover up to 45 − 60 percent of the total oil in place.
An Economic Approach to Gas Flare-down in a Selected Field in Nigeria
Authors: Adewale D. , Joshua Ogunrinde O. 
Published: February 2011

Abstract
The paper evaluates the economic and financial viability gy of flaring reduction options in a selected field in Nigeria. ia. Consequently, this research will focus on Identifications of current options in gas utilization.Factors affecting the selection of a particular option.
Nigeria flares 17.2 billion m3 of natural gas per year in i the Niger Delta. The natural gas flared is more than any ther country in the world. Nigeria has reserves of about 187 trillion cubic feet of natural gas, and 3.5 billion cubic feet (1,000,000,000.m3) of Associated Gas (AG) produced ann annually, 2.5 billion cubic feet (70,000,000m3), or about 70% is wasted as a result of flaring. This equals about 25% of UK's total natural gas consumption and it's the equivalent of about 40% of the entire African continents gas consumption in 2001. The annual gas wasted due to flaring g is estimated to cost the country about $2.5 billion annually. This gas flaring expends huge amount of energy and causes environmental degradation and this paper focuses on the benefits that can be derived from gas and its impact on the local economy and the environment. Global Gas Flaring Reduction (GGFR) initiative was used to perform an economic and financial analysis. Using inputs like, daily gas production, price of diesel and fuel, distance to power grid amongst others.
This paper therefore concludes that the local livelihood in the Niger Delta will be significantly improved by promoting a shift from gas flaring to gas gathering for use as a gaseous fuel and for electricity generation. Also, environmental prone diseases will be reduced and agriculture will be enhanced in the Niger delta area. Although there is a great technical and cost involvement, this project is a worthy investment. The gas flare-down will also help to combat Global climate change which United Nations Environment programme (UNEP) is advocating throughout the world in Copenhagen in December 2009 which is mostly caused by global warming.
Improving Oil Production and Recovery Using Reservoir (Fluid) Surveillance Mapping: Niger Delta Example
Authors: U Ileagu Charles , Yahaya Ismael , Arit Igogo , Marcel Onyekwe 
Published: February 2011

Abstract
As the oil production of mature reservoirs declines and budget constraints continue to limit rig-based well interventions and infill drilling, the need for practical and cost effective methods of identifying and recovering remaining resources become increasingly essential. The Reservoir Surveillance Mapping (RSM) method, also referred to as ‘the poor engineer's simulator’, provides a result-oriented means of identifying and accelerating oilrecovery.
This paper describes practical aspects of RSM efforts in a Niger Delta asset, that involved an integrated reservoir-wide management process with the objective of not only understanding subsurface dynamics during production but also delivering a future work programme for the asset's reservoir blocks.
Diagnosing Wellbore Failures What are We Doing Wrong?
Authors: Dosunmu Adewale , Bose Ekeinde Evelyn 
Published: February 2011

Abstract
Assessment of wellbore failure involves several parameters for which data may be readily available. Since wellbore failure problems in exploration and production drilling cost the drilling industry certainly more than $100 million per year worldwide and may approach one billion dollars annually.
The rock mechanic input data required for analysis are complicated and costly to acquire which causes failure in the analysis and as a result leads to wellbore collapse. This project presents a computer model software which takes into account mud chemistry, Mohr-Coulomb model, Mogi-Coloumb model, Drucker-Prager and Modified Lade Model and uses the latest Microsoft. Net Technology (Microsoft Visual Basic 2008) as the software backbone.
Most of the overburden consists of shale formations. In highly reactive shale sections, mud chemistry is of extreme importance in addition to the mechanical aspects of the instability. The mud composition changes as shales slough and disperse into the mud column, or by chemical interactions between the minerals in the formation and the mud. This indeed will alter mud property and rheology and cause well bore failure.
Mohr model involves only the maximum and minimum principal stress and assumes that the intermediate stress has no influence on rock strength.
Results from the software indicate that modified Lade criteria tend to be more realistic than the Mohr-Coulomb and Drucker-Prager model.
Furthermore, the software shows that for any rock type an increase in borehole inclination angle increases the rock borehole instability. Sensitivity analyses by the software confirm the reliability of the models reviewed.
Successful Application of Formation Pressure Testing While Drilling in High Temperature Tight Gas Field in South Sea China
Authors: Guo Shusheng , Niu Yuqiang , Song Ju , Lim Lee Chin , Yang Xingwang , Zhou Jiasheng , Wang Renyi , Peng Wenfeng 
Published: February 2011

Abstract
Formation pressure and mobility measurements play a critical role in the development and management of compartmentalized reservoirs. Conventionally, wireline formation tester (WFT) tool has been used for such appliations. However, reservoir evaluation becomes challenging in high temperature environment, due to the unchangeable temperature limitations of WFT tools.
This paper presents a case study where formation pressure and mobility are acquired by applying formation pressure testing while drilling (FPWD) at a high temperature (HT) offshore gas well in South Sea, China. With a thermal gradient of as high as 4.5 degC/100m, the estimated formation temperature is higher than the maximum temperature rating of the wireline tools. By integrating detailed pre-job design maintaining the working temperature at acceptable range and real-time monitoring including data quality control and measurement optimization ensuring the functionality of hardware and the quality of measurement, FPWD has successfully revealed the formation properties.
Successful Execution of ‘D Field Compressed Gas Capacity Enhancement Integrated Turnaround’ (DuCIT), Peninsular Malaysia Operations, PETRONAS
Authors: Ismail Firdaus , Razizad Afiq Syazwan , Awang M Zaki , Razali Nasaruddin , Osman Azmee , Hadi Sriyanta 
Published: February 2011

Abstract
D Field is a major oil field located about 130 km offshore Terengganu, eastern Peninsular Malaysia with a water depth of 76 meters in the South China Sea (Refer to Figure 1). The facilities within the field include oil and gas processing plant, water and gas injection facilities, gas compression system and a Floating Storage and Offloading (FSO) where the crude oil is exported (Refer to Figure 2). The field was brought to production in March 1991 with an average oil production of 45,000 barrels of oil per day (BOPD) and peaked at approximately 75,000 BOPD. Water injection has been implemented for pressure maintenance and as part of the field life journey; water alternating gas (WAG) injection will be introduced to enhance oil recovery within the field. Fulfilling the WAG requirement particularly on gas injection, an additional gas compression module called the Compressed Gas Capacity Enhancement (CGCE) was installed to increase the gas compression capacity. In March 2010, D field has successfully completed two major jobs, the CGCE module installation and field turnaround simultaneously under a campaign called ‘D-field CGCE Integrated Turnaround’ (DuCIT). CGCE module installation comprises of the installation of a 900 metric tonne module onto the existing platform and the turnaround execution manages to complete planned activities including surface facility maintenance and well related works within the same period. DuCIT involved two major parties, D field Operations and the CGCE Project Management. With a huge challenge in coordinating a total of 400 personnel and controlling concurrent activities in a high risk operation, the team manages to complete the turnaround ahead of schedule with zero Loss Time Injury (LTI). DuCIT has been recognized as the best turnaround adhering to the requirements of PETRONAS standards on plant operation and capability. Analysis presented in this paper describes important key success factors in DuCIT execution; they are 1) proper turnaround planning, 2) developing excellent teamwork and 3) prominent operation coordination. The paper also describes the mitigation plans that were in place.
Thick Black Liquid Formation in Production Facilities Centrifugal Gas Compressors' Discharge: A Case Study
Authors: Al-Mehthel Rashed , Carvalho Wilfred , Mehdi Mauyed 
Published: February 2011

Abstract

Problem Statement
A thick black hydrocarbon formation was found on centrifugal gas compressors’ discharge end wall and in the downstream discharge isolation valves that were installed in one of Saudi Aramco’s gas-oil separation plants (GOSPs) shortly after the plant commissioning. This phenomenon instigated a thorough process and material compatibility investigation. The mechanical part of this paper explores the reasons behind the compressors’ end wall and discharge isolation valves’ O-rings failure despite the fact that these were made of a material designed to withstand higher than actual and design discharge temperatures. The process section looks at sources of the residue formation at the compressor’s discharge, in particular, the compressor’s suction knock out drums demisters pad design.

Background
The problem was encountered in a gas-oil separation plant (GOSP) that compresses associated gas to a discharge pressure of 450 psig and an operating temperature that can reach 340 °F during the summer season. Thick black liquid was observed leaking from the barrel of the discharge end flange of two high-pressure (HP) gas compressors about a year after the plant commissioning.
The liquid was also observed at the compressor’s balance line (discharge end) on both compressors. A third compressor that operates at a lower discharge pressure and temperature, 105 psig and a maximum temperature of 300 °F, did not develop any symptoms of leaks in spite of operating under sour conditions. After nearly two years of operations, one of the HP gas compressors was dismantled and overhauled to investigate the source of the problem.
The Role of Project Management Team in Waterflood Pilot Project as a Plan for Full Project Development
Authors: Ardianto Reza Nur , Simamora John Hisar 
Published: February 2011

Abstract
Business management of oil and gas in Pertamina, state oil enterprises, was handed over to one of its subsidiaries, Pertamina EP (PEP). With a vast working area of 140,000 km2, consists of 214 field where 80 percent is an old field (mature field or brown field), The conditions that have to be faced are as follows: production from existing field is declining, data is collected and interpreted over a long time period, huge amount of production data, and reservoir model and simulation are not frequently updated
The issue of maintaining production with small investment has changed due to the management and government board that urged to increase oil & gas production as result from national production increasing program. To get better recovery of those brown fields, it is necessary to have a long term project such as EOR. Some screening criteria had been completed to select an appropriate method which could be applied in certain field. It is obvious that the potential increase in oil reverse through EOR is quite significant. Pertamina EP is currently preparing a program Enhanced Oil Recovery (EOR) to be applied in some oil field with subsurface and surface potential consideration.
The implementation of waterflood project in Rantau field was initiated by EOR Department, Pertamina EP. The pilot project which was proposed in two patterns and it was successfully executed in January 2009. The increase in oil recovery by waterflooding results from displacement efficiency and volumetric sweep efficiency when injected water maintains reservoir energy and displaces remaining oil to production well ahead of advancing water.
First Multi-Stage Swell Packers Open Hole Completion in Rub’ Al-Khali Empty Desert: Case Study
Authors: Ekpe Joseph , Kompantsev Andrey , Al-Thuwaini Jamal , Mohammad Emad , Ashoor Ayman 
Published: February 2011

Abstract
Many "poor" gas prospects-particularly ultralow-permeability and porosity unconventional rocks such as tight sand-become economic success when hydraulic fractures are created in the pay zone. The fractures allow a single well bore to contact many thousands of square feet reservoirs. Using swellable packer technology has mechanically simplified fracture job. Using multiple packers ensures the entire zone is treated; or in other words, knowing where the fracture fluid goes once it exits the casing, and how each set of fractures is isolated from another is a key in a successful hydraulic fracture design.
Lukoil Saudi Arabia started an exploration campaign in the Rub’Al-Khali Empty Quarter in 2006 targeting Non Associated Gas and nine wildcat exploration wells have been drilled and evaluated. It was found during the early stages of the exploration that the gas accumulations in LUKOIL Saudi Arabia exploration Area (Block-A), were typically trapped in tight to ultra-tight reservoirs (see Fig. 1). These gas discoveries in the Empty Quarter have occurred in High Pressure and High Temperature (HPHT) horizons at depths between 12,000 and 20,000 ft, where the stress and temperature are extremely high in addition to micro-Darcy levels of reservoir permeability. This has made the exploration activity more challenging.
Figure 1 Location of Project Area in Rub Al-Khali Desert