bluuebunny/crossref_metadata_2025_split huggingface dataset:
Model for Quick Permeability Determination of Niger Delta Sands Using Grain Size Analysis
Authors: Bamisebi Adetiloye J. 
Published: July 2016

Abstract
It generally has been recognized by previous investigators that grain size is a fundamental independent variable controlling permeability in unconsolidated sediments. Several models that have been developed for estimating permeability based on grain size. However, these equations are based on empirical studies, and the results are not necessarily transferable from one location to another. It is therefore important to determine which permeability equations are appropriate for use in the Niger delta basin. The author seeks to establish the use of grain size data from Sieve analysis to determine the permeability of sediments from the Niger Delta area. Sieve analysis experiment was performed on samples from different wells and depths and the grain size data retrieved. Permeability was also determined using routine core analysis methods. Regression analysis tool on Excel was used to derive an empirical relationship to predict permeability from grain size data. Two models were developed and they represented different permeability regimes (k&lt; 1000 md, k≥1000 md). The accuracy of this method was checked by correlation with standard routine core analysis permeability data. Statistical indices showed percentage error (-0.0627%, 0.0008%) and correlation coefficient (r = 0.9844, 0.631). Sensitivity carried out on the model variables showed that the grain diameter and the sorting are the key variables controlling the determination of permeability from these models.
Success Story of Nigerian Content Development Implementation in SPDC Drilling Operations
Authors: Awe S. O. , Eze N. , Akhideno M. , Iyamu I. , Weli I. 
Published: July 2016

Abstract
The drive of Nigerian government to boost economic activities through local capacity utilisation, human capital development and empowerment of indigenous companies resulted in the implementation of Nigerian content development in the oil and gas industry which was previously exclusive to the multinationals. The Nigeria Oil and Gas Industry Content Development Act of 2010 provides the legal framework to facilitate and promote mandatory participation of companies owned by Nigerians in the high-risk and high-cost petroleum industry. Prior to the enactment of the act, insignificant number of Nigerian companies had the financial strength and technical know-how required to be competitive in the petroleum sector compared with the well established multinational operating and service companies. These factors made compliance with the requirements of the act a daunting challenge for the sector.
Historically, The Shell Petroleum Development Company (SPDC) has played important roles in the development of various aspect of petroleum industry in Nigeria owing to its visionary leadership position in the sector. The SPDC began the Nigeria dontent Development (NCD) implementation in various aspects of its business right from the time the idea was first muted in 2001. This disposition of the company to NCD ensured that by the time the act was enacted in 2010, competent local contractors in drilling operations, production maintenance, facilities construction and so on had been developed. The transition of the SPDC from the implicit period of NCD implementation to the period when compliance to the provisions of the law became mandatory was smoothened by the development of the local contractors ahead of time.
The approach taken by the SPDC contributed to the realisation of major success stories in various arms of its operations. One of such achievements is the degree of compliance of the drilling operations department with NOGICD Act requirements. This paper details various schemes that were employed by the drilling and contracting departments in conjunction with the National Petroleum Investment Management Services (NAPIMS) and the Nigeria Content Development and Monitoring Board (NCDMB) towards the realisation of the nation's aspiration of domesticating technology, human capital development, financial empowerment and economic development, and then leveraging the resources available in the oil and gas industry.
Study of Fines Mobilization by Flow Rate in the Presence of Aluminium Oxide Nanoparticles
Authors: Ogolo Naomi A. , Ezenworo Ebuka J. , Ogri Emeka , Wali Samuel M. , Nnanna Echi C. , Onyekonwu Mike O. 
Published: July 2016

Abstract
One major factor that triggers fines migration in formations during hydrocarbon production especially in the presence of water is high flow rates. Low flow rates have been recommended to prevent fines mobilization but this solution is not always practical because there is a critical rate below which production becomes uneconomical. It is the objective of this work to find out if the presence of Aluminium oxide (Al2O3) nanoparticles in sand can allow for a relatively high flow rate without mobilization of the clayey fines. The experiments were conducted under different flow rates ranging from 3 – 9ml/min. while flowing brine of 30g/l salinity through the sand until breakthrough of fines occurred. In the first phase of the experiments, the clayey fines were contained in the sand samples while in the second phase, the fines were contained in the injected fluid flowing through the sand.
Experimental results showed that relatively large volumes of fines free brine can flow through sands containing Al2O3 nanoparticles at relatively higher flow rates without fines mobilization which is in contrast to the reference experiments. At a flow rate of 9ml/min. for the first phase of experiments in the presence of medium crude, fines breakthrough occurred at 1pore volume for the reference experiment while fines breakthrough occurred in the samples containing Al2O3 nanoparticles after flowing more than 12pore volumes of brine through the sand. For the second set of experiments, fines breakthrough occurred at 1pore volumes for the reference case while it occurred in the samples containing Al2O3 nanoparticles after flowing about 6pore volumes of brine at a flow rate of 5ml/min. in the presence of medium crude. This implies that at certain increased flow rates, large volumes of brine can be produced from sands containing Al2O3 nanoparticles before clayey fines are mobilized compared to when Al2O3 nanoparticles are absent in the sand. This indicates that Al2O3 nanoparticles have the capacity to delay fines migration in sand at relatively high flow rates.
Successes and Challenges in Delivering Deviated Gas Wells
Authors: Festus Ijeoma , Okongwu Obinna , Mfonnom Goodluck , Okonkwo Chukwudi , Okogbe Bolaji , Orimoloye Samuel 
Published: July 2016

Abstract
The prospects for gas development for domestic use and export which is driven by the national gas policy and incentives, has sprang up a lot of gas development projects in Nigeria such gas power generation plants, liquefied natural gas plants, gas-to-liquids projects, associated gas gathering projects etc. With these projects, the Nigerian government intent is to raise income from Nigeria's huge natural gas resources, raise gas utilization, achieve zero gas flare and create permanent employment for thousands of Nigerians. This in turn has created huge deficit between local gas production and the demand.
Seplat Petroleum Development Company in her JV operation in OML 4, 38 and 41 has cumulative gas reserves of approximately 1820 Bscf with two gas processing plants, the Oben gas plant and Sapele gas plant. Seplat cumulative gas production as at 2014 was at 147mmscf while the company's base domestic demand stands at 300 mmscf. Owing to this deficit and the prospective growth in demand due to increasing gas infrastructures for power and the manufacturing sector, Seplat embarked on gas drilling campaign from 2014. Since inception of the Seplat in 2009 to date, a total of sixty one wells has been drilled and out of which, twelve were gas wells (six new wells and six workover wells). The six new gas wells which consist of Oben 43, Oben 44, Oben 45, Oben 46, Orogho 7 and Okporhuru 8 were all deviated wells as shown in Figure 3. Approximately fifty percent of the proposed 2016 drilling work program are new drill gas wells and the percentage is expected to increase in the coming years.
This paper focuses on the challenges and successes which were recorded during the planning and execution of the deviated gas wells.
Surface location selection and well trajectory optimization to meet the geological objectives. This was achieved by deviating the wells between 45°to 75°inclination to increase the production zone interface in thin reservoirs. Optimum completion tubing size and wellhead selection. This was achieved by modifying the 13 5/8" x 9 5/8" tubinghead spool to 13 5/8" x 10 ¾" tubinghead spool without compromising the wellhead integrity in order to deploy a swaged 9 5/8" x 10 ¾" production casing string and the completion tubing string. Achieving effective zonal isolation on the production casing primary cement job across the gas bearing sands. This was accomplished by adopting two non conventional techniques vis a vis deployment of 10 ¾" x 9 5/8" combination wiper plugs and cost effective preflush "Gustacho Pill" to remove gelled mud, allowing a better cement bond with casing and formation. Effective sand exclusion. Utilized 8 ½" x 10 ½" bi-centre bits to underream the reservoir sections to 10 ½" for higher annular clearance required to install premium screens for external gravel pack and maximize production.
Fast-Tracking Field Development in a Green Field by Eliminating the Need for Appraisal Using Multidisciplinary Evaluation Methods
Authors: Kakayor Omagbemi George , Oragui Ijeoma , Esho Muyiwa , Anyaehie James 
Published: July 2016

Abstract
Field development is heavily contingent on the proper delineation of the field's resource volume along with the subsurface uncertainties. For green fields, appraisal drilling reduces uncertainties, but has the potential of cost escalation and delays in project timelines thus making projects less competitive. This study highlights how a fast tracked appraisal/development strategy for 1.7 Tcf of gas development project worth $800mln was developed and approved by the regulatory authorities.
The GATOE field under review is in the South East of the Niger delta, Nigeria. The field is 80 km2 in aerial extent. It consists of 11 stacked hydrocarbon-bearing reservoirs of varying thicknesses and, is penetrated by 5 wells. Seven (7) of these reservoirs (3 AG and 4 NAG) with GIIP of 900 Bscf that are ‘ready-to-go’ gas resource were captured in the ‘Tranche-1’ development scope. The remaining 4 reservoirs which are AG reservoirs with uncertainties in the actual oil column were grouped for trench-2 development but will be appraised during the Tranche-1 execution phase.
Usually regulatory approval for field development is secured post appraisal drilling. This study however, proposes a concurrent field development and appraisal scheme where development wells (for fairly known reservoirs) are used to also appraise reservoirs with appraisal needs. Thus significantly reducing the number of appraisal wells (from 3 to 1) and ensuring the delivery of fast-tracked field development (early ‘First-gas’ date). The only appraisal well will be drilled at the tranche-1 execution stage. In order to achieve this, a multidisciplinary evaluation of all available data was done in addition to the use of reliable technology. This is with the aim of demonstrating that the fast-tracked gas development will not jeopardise the recovery of any potential oil that may be proved from the appraisal exercise.
This study demonstrates the viability of a field development strategy in which ‘freezing’ of a development concept prior to full field appraisal can be achieved. The outcome is a massive reduction in appraisal costs and accelerated field development.
Guiding Seismic Interpretation Using Predictive Structural Models: Transfer Accommodation Faults in Onshore Niger Delta Reservoirs
Authors: Manuel Tekena , Glukstad Miguel Mora , Amrasa Kefe , Esho Muyiwa 
Published: July 2016

Abstract
There is general awareness of the importance of transfer accommodation faults towards controlling sediment dispersal, migration and hydrocarbon trapping in the deep-water thrust belt of Niger delta., These types of faults, although less understood, are also active in the onshore extensional part of the basin, where they can also exert important controls in sediment transport and/or reservoir geometry. These faults act as transfer mechanisms between major growth faults and provide a mechanical way to "accommodate" the non-orthogonal gravitational deformation. Although seismically we often map one single fault plane, these faults are more complex and could have a series of strands, which are often below seismic resolution.
The strands from transfer faults could also control deposition as they act as barriers that hold back sedimentation helping to delineate the depocentre on the hanging wall (HW) of the main normal fault. A gas well targeting an accumulation on the footwall (FW) of a major growth fault, missed its target by 149 ft. Using innovative "in house" processing technology, 3D PSDM data showed that the new well was drilled between two small crestal collapse E-W normal faults, which are limited to the east by a strand of a major NNE-SSW transfer fault.
This paper highlights the results of the new seismic interpretation, which looked at the geometry of the transfer fault in more detail and concluded that the interaction between the crestal collapse faults and the strands of the transfer system were important in the structural configuration of the target reservoir.
This type of approach is useful in areas of fault-fault intersection or poor quality seismic data where the presence of smaller scale accommodation faults can significantly affect depth prognosis during well planning and static volume computation.
Application of Web-GIS Technologies to Globally Manage Petroleum Asset Information
Authors: Amouroux Jean-Michel , Aneke Harold , Leclerc Jean-Charles 
Published: July 2016

Abstract
The ability to access and share valid and up-to-date technical information is a key element of our operational efficiency with the follow-up of our projects and operations. This will have a critical impact in case of incidents and/or crisis situations, as this could happen in sensitive area like Nigeria.
In case of a major crisis, we must be able to restore access to the identified critical facilities stored in GIS datasets within a time limit of 4 to 8 hours!
A New Approach in Rock Strength Constraining Using Petrophysical Logs for Effective Real-Time Wellbore Stability Management in Normal Stress Regimes
Authors: Bassey Akong , Usim Mike , Otutu Friday , Dosunmu Adewale 
Published: July 2016

Abstract
The geomechanical knowledge of rocks physical and mechanical properties could reduce the NPT incurred while drilling and production of a reservoir to a large extent by selection of proper/optimum operating envelope. Hence, a field development plan for each oil/gas field may contain optimized geomechanical procedures that take into accounts the rock mechanical principles and failure scenarios. "The unconfined compressive strength (UCS) and internal frictional interplays of rocks is the important rock mechanical parameters that plays crucial role when drilling an oil or gas wells". "(UCS) is the stress level at which rock is broken when it is under a uniaxial stress state (Bruce et al 2004)"; it can be used for real – time wellbore stability evaluation, bit selection management, and design of enhanced geomechanical earth models and cap integrity evaluation. Rock strength can be estimated along drilled wellbore using different approaches, including laboratory tests, core – log relationships and rate of penetration models. The benefit of a petrophysical log- derived method is that, it provides continuous strength profiles with depth. This is useful in delineating differences between near uniform zones, and identifying weaker zones. There is also a cost advantage in obtaining these data without having to perform extensive laboratory testing throughout the core interval.
"In this study, new equations for estimation of rock strength in Niger Delta formations are formulated based on empirically derived models that accommodate petrophysical log information such as the degree of shaliness detected over the entire logged interval, corresponding to shale and sand units (Fjaer, et al. 1990), lithology index etc., hence they are utilized for estimation of the rock strength profile for easy and effective geomechanical evaluations" (Dosunmu 2007).
A geomechanical enhanced framework coupled with discrete finite element analysis is utilized for prediction of UCS in any predefined well trajectory and batch depth analysis on the course of this research (study). Cross/post – validation shows that, the results from the formation discretization were compatible with realities (based on MEM utilization). This approach has proven to be useful for estimation of rock strengths and frictional interplays in any design well trajectory prior to drilling (predrill scenarios). Above all, it helps to determine the minimum and optimum mudweights required for real – time wellbore stability management during drilling, POOH, casing running and cementing, helps in preventing unplanned events leading to outrageous NPT's (Otutu 2013)
Role of Fault Transmissibility Analysis in Achieving Adequate Simulation History Match for a Light Oil Reservoir
Authors: Olu Okpani , Anil Ambastha 
Published: July 2016

Abstract
Reservoir simulation history match was recently carried out for the A7 reservoir located in the Niger Delta. The A7 reservoir is divided into two compartments ("Main" and "West") by a fault ("Center Fault") such that at initial conditions, the compartments have common Original Oil Water Contact (OOWC), but different Original Gas Oil Contact (OGOC). The difference between the OGOC of the two fault block is 24ftss. One well ("Well-A7") has produced from the reservoir in the West compartment. Well-A7 has been on production for nine years with three distinct produced GOR periods: Low-GOR, Mid-GOR and High-GOR periods.
Initial attempt to history match the performance of Well-A7 by assuming that the Center Fault was completely sealing resulted in the inability to match the Mid-GOR and High-GOR production periods. Consequently, the sealing potential of the Center Fault was further analyzed in detail. Examination of the Center Fault shows that the Main and West compartments have sand-to-sand juxtaposition in part of the gas zone; with the pressure difference between the gas zones of the two compartments at initial condition estimated at about 8 psi. This implies that the threshold pressure of the Center Fault was greater than 8 psi. Thus, it was presumed that the Center Fault was sealing at initial condition, but became non-sealing at dynamic condition when the pressure difference between the two compartments exceeded the capillary threshold pressure of the Center Fault.

Results/Conclusion
The GOR, water cut, shut-in-bottom-hole-pressure and flowing-well-pressure were history matched for Well-A7. Several history-match parameters were identified prior to history matching, but the parameters that had the most significant impact on history matching were the transmissibility and threshold pressure of the Center Fault. Good quality history-match was obtained with a fault threshold pressure of 25 psi. Some forecast results using this history-matched model are also presented.
HPHT Well Integrity and Cement Failure
Authors: Wilcox Bomá , Oyeneyin Babs , Islam Sheikh 
Published: July 2016

Abstract
A petroleum wellbore must have complete zonal isolation to maintain its integrity. This is primarily achieved by the cement sheath barrier that sits between the casing and rock formation. However, effective zonal isolation can be adversely affected by conditions such as high pressures, high temperatures, and high hole angles. These conditions are increasingly popular in deep-water drilling and can compromise the strength and integrity of the cement sheath if not anticipated early.
This paper presents some critical issues and factors that affect well integrity in HPHT wellbores. It also presents an analytical model of the interaction between the casing, cement sheath, and rock formation. This model also contains mathematical relationships for the interfacial pressures at the casing-cement and cement-rock contacts/interfaces. The study was limited to vertical wells as this allowed us, for purposes of symmetry, to analyse the casing-cement-formation relationship as a composite cylinder. The area of the wellbore that was analysed is the pay-zone area where the relationship between the casing, cement and rock formation is represented by a concentric composite cylinder. This paper is part of an on-going research project on well integrity at Robert Gordon University, United Kingdom.
Energy Security, Affordability and Availability: Implications on Economic and Industrial Growth in Nigeria
Authors: Igbokoyi Alpheus O. , Iledare Wumi 
Published: July 2016

Abstract
Energy is fundamental to the national economic and industrial growth. Therefore, access to affordable and sustainable energy is essential to the functioning of a national economy. In most developed nations, energy policy tends to focus on energy security, environment, economy and affordability of energy. No nation can grow beyond its energy development and management pedigree. While energy development as a source of income through exportation of hydrocarbons brings monetary wealth, energy consumption in the local economy is a good indicator of the socio-economic wellbeing and industrial growth of a nation. In other words, the prosperity of all sectors of a nation economy is tied to the prosperity and effective management of the energy sector. Nigeria continues to produce bulk of its energy resources for export over the decades. Unfortunately, the domestic economy continues to suffer a significant setback because of inadequate energy to energize the productive sector of the local economy. This paper examines energy consumption per capita and the economic data in Nigeria, and compare with the data from the United State of America as a developed economy, and China as a growing and emerging economy. Based on the comparison, we then forecast how much liquids petroleum will be needed to support the socio-economic life, industrial growth and the transportation in the country. Different scenarios are run based on the rate of liquids petroleum consumption in China and Africa. Our analysis shows that Nigeria might become an importer of crude oil between 2030 and 2035 as the country economy, industrial activities and population grow.