bluuebunny/crossref_metadata_2025_split huggingface dataset:
Realtime Aaquisition of Formation Pressure Data For Reservoir Characterization and Safe Drilling
Authors: Umeonaku Loretta , Adegboye Philip , Ubadigha Emmanuel , Ibrahim Hamza , Anwana Francis , Omale Gabriel 
Published: July 2019

Abstract
Formation Pressure data is a key parameter for in-depth characterization of a reservoir's potential and capacity to produce hydrocarbon. Pressure data are analyzed to confirm fluid interface, fluid type as well as to understand reservoir connectivity/isolation and compartmentalization if any, needed to finalise on the completion strategy to be utilized for optimal production. Acquisition of this data while drilling provides early and reliable information for decision making in optimising the drilling process.
This paper demonstrates the use of Formation Pressure While Drilling (FPWD) tool to acquire formation pressure data. It examines the successful wellsite execution of FPWD service deployed in 3 deepwater wells in the Gulf of Guinea. It discusses operational sequence, quality of the results and how the operator utilized acquired data. In Well A, the test objective was to establish reservoir connectivity between a producer and an injector. For Well B, acquired pressure data was crucial in finalizing completion strategy. Well C shows how the direct pressure measurements were utilized to update the mud program in real time while drilling.
Finally, this paper reemphasizes the value of FPWD by outlining how acquired pressure data met clients objectives by providing valuable quality data which provided great insight in reservoir characterization and safely drilling the wells to Total Depth.
A Computer-Aided Hydrate Management System
Authors: Lawson-Jack Databa , Odutola Toyin , Chukwu Ogbonda Douglas 
Published: July 2019

Abstract
In this study, a computer-aided system for effective hydrate management is presented. A flowchart was developed to suggest possible intervention approaches to follow in the event that hydrates are restricting flow in flowlines. Using VBA® in Excel, a worksheet was developed to serve as a direct means of proposing an intervention approach to adopt after confirming the cause(s) of hydrate formation in the flowline that is monitored. The worksheet created suggests intervention approaches in a matter of seconds after a series of prompts to input the identified causative agents. The main causative agents considered were hydrate formation temperature (HFT), hydrate formation pressure (HFP) and Sufficient Gas/Water. Six scenarios of causative agent occurrences were considered. Scenario 1 was a combination of HFT, HFP and sufficient gas/water, the proposed intervention was to depressurize, heat flowline, carry out chemical inhibition and dehydrate. Scenario 2 was a combination of HFP and HFT, the intervention proposed was to depressurize, heat flowline and carry out inhibition. Scenario 3 was HFP only, the intervention strategy proposed was to depressurize and carry out chemical inhibition. Scenario 4 was a combination of HFT and sufficient gas/water, the proposed intervention was to heat flowline, carry out chemical inhibition and dehydrate. Scenario 5 was HFT only, the proposed intervention strategy was to heat flowline, carry out chemical inhibition. Scenario 6 was a combination of no HFP, HFT or sufficient gas/water, the proposed intervention was that the causative elements be checked again since hydrate presence in the flowline had been previously confirmed.
In-Situ Burning As An Oil Spill Control Measure And Its Effect On The Environment
Authors: Ekperusi Abraham O. , Onyena Amarachi P. , Akpudo Marvellous Y. , Peter Chibuike C. , Akpoduado Christiana O. , Ekperusi Omesiri H. 
Published: July 2019

Abstract
In-situ burning (ISB) is a process of burning crude oil at the point of spill, as a containment measure for oil spill control. It is usually applied as one of the last resort to prevent spilled oil from reaching ecologically sensitive habitats and recreational activities in coastal areas. While booms, skimmers and dispersants may be very expensive and difficult to deploy, ISB is relatively inexpensive, making it attractive to oil spill responders. ISB can be applied in marine, coastal, freshwater, arctic and terrestrial environment. Factors affecting burn efficiency include water density, type of oil, slick thickness, degree of emulsification and weathering, flame coverage, wind speed and wave action. Although ISB has been very successful in removing spilled oil from polluted environment, there are great concerns about the transport and fate of emissions and residues from the burned oil, on the environment, biodiversity and public health. Potential air pollutants from oil burning include particulate matter, nitrogen oxide, sulphur dioxide, carbon monoxide, carbon dioxide, volatile organic compounds, and mixtures of various polycyclic aromatic hydrocarbons. Many developing nations lack the legal and regulatory frameworks, the contingency planning process and human resources to monitor the implementation of ISB in the oil and gas industry, making the practice very complicated and of imminent danger to society. There is also need to develop alternative measures to ISB in order to mitigate the effects on the environment and human population.
Global Warming Issues, Challenges & Vulnerable Africa – Cleaner Energy Possibilities, Emission Reduction Analysis and Mitigation Strategies
Authors: Umeh Ebuka , Onyekperem Cyprian 
Published: July 2019

Abstract
This paper is intended to tackle and treat the subject of global warming which includes its components, current issues, trends and challenges to enable us to add our own mitigation measures to support the global efforts on its reduction. The caustic effects would be analyzed using environmental data gotten from Environmental Impact Assessment (EIA) studies and Environmental Evaluation Report (EER) from various field locations in the oil production fields in the Niger Delta region of Nigeria. Analysis of the various cleaner energy alternatives other than fossil fuels would be done, with individual challenges of these alternatives been highlighted, from which a projection for the zone under study would be done using graphs and data plotted in Excel. Mitigation strategies has been suggested and backed with adequate recommendations that are gotten from sample opinions from experts in environmental matters in the oil and gas industry.
Dynamic Risk Assessment – A MacGyverism to Worksite Incidents
Authors: Umeh Ebuka 
Published: July 2019

Abstract
The industry is in constant research with consistent efforts to ensure that the no/less incidents occur during the course of operations. Notable and popular slogans/rules have been adopted among engineering and oil & gas organizations over the years in the industry to intimate the need for safe activities to be performed among staff. Slogans like Goal Zero, Golden Rule dictum, "Safe…Yes we can", Life Saving Rules, "No Wahala…Take 5" and many others have been used in recent times to inculcate the culture of safety and situational awareness in the mind of the work force. Tools like check cards, stickers, safety IDs and banners are also quick reminders of the environment being operated on.
However while all these tools are fairly efficient, the need for proper risk assessment cannot be over-emphasized at all times before a job to be done can be certified safe. Worksite Tools like toolbox talk, last minute risk assessment (LMRA), Job Hazard Analysis (JHA) and post job debrief are veritable towards achieving this goal. But while risk assessment before the job commences is important, of equivalent or even much importance is the one conducted during the job and this is called dynamic risk assessment.
This paper presents an approach and exposition of the risk assessment plan in the operations level in the oil and gas industry. It also discussed on the methods to be deployed a successful risk assessment and buttress further on static and dynamic risk assessment as it concerns operations in a gas process plant. A new conceptual risk assessment model has been developed. A case study was treated from Atabala Plant which is a gas processing facility in the south southern Nigeria.
Reservoir Navigation in Njaba Field – Challenges, Procedure and Results
Authors: Ndokwu C. , Amadi K. , Toyobo O. , Okowi V. , Ajisafe I. , Inenemo A. 
Published: July 2019

Abstract
Due to the low oil price, Exploration and Production (E&P) companies are driven to reduce the cost per barrel of oil equivalent (BOE). The application of reservoir navigation services, in the placement of high angle and horizontal (HAHZ) wells in the sweet spot of reservoirs, has aided in meeting this economic need of the E&P, while also improving hydrocarbon recovery.
Reservoir navigation services (RNS) can be regarded as another tool for improving the odds of success while drilling of HAHZ wells. This service involves the integration of real-time data (deep-reading azimuthal resistivity, gamma-ray, density image, resistivity image logs, near bit inclination and a fit for purpose rotary steerable system) to accurately position the well-bore relative to specific subsurface targets, while remaining within the constraints of the drilling and completion program. RNS also require a software package capable of pre-well modeling, displaying the acquired real-time data and interactively adapting the model to the real-time data.
Geosteering in Njaba field involved a comprehensive pre-well planning, discussions, documentation and management approved decision-tree. Using three wells for this study, this paper describes the challenges, procedures and results of geosteering in Njaba Field located on-shore Niger-Delta. From different entry points, wells NJX1, NJX2, and NJX3 were planned to drain the same reservoir and optimize hydrocarbon recovery within the reservoir. Some of the challenges encountered includes geosteering the wellbore above a pre-determined production TVD hardline while simultaneously avoiding drilling into an overlying undulating shale cap rock, vertical seismic uncertainty and undulating formation boundaries.
The Effect of Monovalent and Divalent Ions on Biodegradable Polymers in Enhanced Oil Recovery
Authors: Eiroboyi I. , Ikiensikimama S. S. , Oriji B. A. , Okoye I. P. 
Published: July 2019

Abstract
The stability of polymers used in enhanced oil recovery especially in polymer flooding is largely based on their ability to withstand challenging reservoir conditions such as the effect of high salinity and high temperature. Polymers like Hydrolysed Polyacrylamide (HPAM) and its derivatives lose their viscosity when subjected to high salinity conditions due to the screening of the ions of the polymer backbone chain. HPAM is not only sensitive to salinity and temperature but also very susceptible to shear degradation. Research show that Xanthan gum; a commercial biopolymer used mostly in polymer flooding show more tolerance to shear degradation and even better stability to salinity and temperature than HPAM but not frequently used due to its high cost.
The work is centered on the study of stability of some selected low cost biopolymers like Guar gum, Locust bean gum, Gum Arabic as well as the commercial Xanthan gum. This study captures the effect of monovalent and divalent ions on the polymers in order to establish their degree of stability and the impact of these ions with respect to varying salinity conditions. The rheological performance of these polymers were analysed using both NaCl and CaCl under both medium and high saline conditions which are similar to reservoir conditions. The results show that all polymers show appreciable resistance and stability when compared to Xanthan gum especially Locust bean gum in the presence of monovalent ions, Gum Arabic displayed the least tolerance to the ions. Although, the presence of divalent ions had more impact than the monovalent ions on all polymers' stability, however, higher concentrations of the polymers resulted in more resistance to the presence of these ions.
Towards Information Transparency: Current Posture and Advocacy for Open Data Systems for Efficiency, Equity and Justice – The Nigerian Oil and Gas Experience
Authors: Ante M. A. , Ante A. E. 
Published: July 2019

Abstract
Transparency in information is one of the most important undertaking that the government in collaboration with oil and gas stakeholders can offer to the public. Open, and therefore, accessible, nonproprietary data in the current information age is a tool for improved governance, transparency and innovation.
The oil and gas industry is a huge data generator through its daily operations, it is a leader and in fact, a home to big data. From existing development assets, to supply chains, customer relations etc, data provides a competitive advantage for organizational growth and management. Beyond the strategic opportunities that big data provides within the industry, is the enormous capabilities that big data through open data initiatives can have on company-community relations.
In this paper, we examine the various acts and legislations governing oil and gas industry operations and their position on data transparency. Our examination sheds light on current positions of the tripartite of law, policy and practice and the demonstrated gaps between this tripartite. In addition to the legal analysis, we also examine the issue of open data through the petroleum engineering prism. The benefits and significant impact a movement in open data will deliver to the industry are also examined which include but are not limited to: addressing public concerns and increasing community workforce participation and protection of oil and non-oil natural resources.
Finally, because discussion on open data is incomplete without the necessary data literacy skills needed to utilize, analyze and draw meaningful conclusions from data, we examine how best we can increase these skills within the community to bridge the information divide.
As we enter 20 years of steady democracy and political process in Nigeria, open data will certainly disband doubts and fake news in our energy conversations as it will provide a level playing field for all parties. Public discourse will be more focused on facts and lead to improved and sound decision making.
Petrophysical Evaluation of the Reservoir in the K - Field, Offshore Ghana
Authors: Anumah Prosper , Mohammed Shaibu , Sarkodie-Kyeremeh Justice , Aggrey Wilberforce Nkrumah , Morgan Anthony 
Published: July 2019

Abstract
Reliable assessment of the petrophysical properties of hydrocarbon-bearing reservoirs is essential for the estimation of hydrocarbon reserves, identification of good production zones, and assessing the need for hydro-fracturing jobs. The K-Field although discovered in the 1970s is yet to be developed.
In this study, well logs from the wells drilled in this field were analysed with the primary objective of determining the petrophysical properties of the reservoir zones using various estimation models. From the log readings, the reservoir sands containing hydrocarbons in the field are found to be located at the Mid Turonian (90Ma)-Intra Upper Albian (96.5Ma) and Intra Upper Albian (98Ma). The porosity was determined using the density log and crossplots. Archie and Simandoux correlations were utilized in the determination of the water saturation. Permeability was estimated using Timur, Tixer and Coates correlations.
The findings after the petrophysical evaluation indicate that the wells entered formations with good reservoir quality in terms of porosity, which ranges from 16.12% to 20.97%. In relation to hydrocarbon saturation and permeability, two of the wells gave better results suggesting that they were drilled through the productive part of the reservoir. Nonetheless, the average permeability of the reservoir is estimated to be very low. This suggests that in the field development planning, well stimulation methods should be incorporated to aid the ability of the reservoir rocks to transmit fluids into the production wells.
Maximising Oil Recovery in Mature Water Floods Using Automated Pattern Flood Management
Authors: Okon Edet Ita , Adetuberu Joseph Adeoluwa , Appah Dulu 
Published: July 2019

Abstract
One of the most significant challenges for extending production life in mature waterflood fields is high water production. Couple with high reservoir heterogeneity, extensive layering and faulting, these fields often developed irregular flood patterns after decades of production which compounded the challenge to optimizing recovery from these fields. The severity of this problem can be seen in the Niger Delta oil fields where there are several matured fields that are producing at high water cut after many years of water flooding. The main objective of this study is to maximize oil recovery from a matured waterflood oil field while reducing the water cut. To achieve this objective, simulation studies were conducted on two cases scenarios. The first case was modelling and running waterflood simulation studied without applying pattern flood management (No PFM) while the second case scenario was done by exploring an automated pattern flood management (PFM). This was done with the aid of Petrel E&P software platform and ECLIPSE FrontSim to efficiently optimize the rate of water allocated to individual injectors. Using data from one of the oil fields operating in the Niger Delta, their performances were compared. The PFM gave the best result with a cumulative oil production of 30,727,470 STB when compared with the case of No PFM which gave a cumulative oil production of 26,968,224 STB (about 12% increase in oil recovery). The PFM water cut was 16% when compared with the case of No PFM which gave a water cut of 47% (about 63% reduction in water production). Hence, The PFM approach has made it possible to reduce water injection in more than 30% of the injectors while more than 62% of the producers experienced increase production and reduced water cut. The productivity increased upon automation of the workflow will enable engineers to identify the optimal injection allocation factors. It will also help engineers to understand and produce from the reservoir at an optimized decline rate and ensure the increase in ultimate recovery.
Cassandra: A Model and Simulator Developed for Critical Drawdown Estimation in Unconsolidated Reservoirs
Authors: Ehihamen Precious 
Published: July 2019

Abstract
Without doubt, one of the most frequently occurring problems in production facilities with dire consequences is sand production. Sand production refers to the continuous flow of formation grains alongside reservoir fluids during production. It is a problem that is more associated with unconsolidated reservoirs such as those present in the Niger Delta. Some of the problems associated with sand production include stabilization of emulsion, vessel blockage, erosion of vessels and reduction in separation effectiveness (Bibobra et al, 2015) all of which have economic consequences, thus, can render companies bankrupt.
In a bid to avoid the aforementioned problems, many sand control measures have been developed, however, with increase in effectiveness in handling sand comes a corresponding increase in cost, hence, necessitating a feasibility study to ascertain their viability. Many authors have developed mathematical models useful in predicting sand production in reservoirs. These models have proved to be useful tools in sand control viability studies. Geomechanical parameters like principal stresses have been useful in these models. However, many of these models developed have turned out complex, requiring difficult-to-obtain parameters or having low level of accuracy when compared to observed field data. In this paper, a mathematical model was developed by modifying the work of Oluyemi and Oyeneyin (2010) who developed a simple mechanistic model requiring few and easy-to-obtain input parameters. A simple simulator, named Cassandra, was then designed using Python Programming Language so as to aid the estimation process.
After validation with field data from different reservoirs, it was found that Cassandra gave results very close to observed field data, in fact, it only possesses about 8% absolute error. The model also performed excellently when compared to existing models. This software, thus, proves to be a valuable tool in any sand production analysis.
Reducing Drilling Operations Cost Through Rental Inventory Management - A Case Study
Authors: Numbere Otokini , Aigbedion Prince , Okoli Ugo' , Okubor Eleanor , Olugbesan Babatunde , Ntiwunka Greg 
Published: July 2019

Abstract
In a regime of volatile oil prices, it has become increasingly important to plan and deliver cost effective wells safely. Typically, this is achieved by optimizing technical details in planning and execution phase; however, an often-overlooked area of optimization is the management of rental tool inventory and the associated logistics. This area is usually subject to cost overruns due to insufficient tracking of equipment from mobilization through its use at the rigsite, resulting in late demobilization and incurring of additional cost by operators.
To completely eliminate these unwanted costs, a web/intranet based, equipment tracking solution which interfaced with the existing enterprise resource planning (ERP) platform (for contracting and procurement information) was designed and implemented by Addax Petroleum Nigeria to track and monitor the movement of rented equipment between service providers, logistics base and operations base. It ensured the effective tracking of rented equipment upon mobilization up till demobilization; this helped to prevent cost overruns for rented equipment during the drilling campaign. Daily reports and notifications were also provided to all key personnel on rented equipment status and it ensured a collaborative workspace for drilling team members to manage rented equipment movement internally.
The rentals inventory tracking application (RITA™) software was deployed during a six-month drilling campaign in 2017/2018. It provided comprehensive tracking for equipment mobilized to the rig, eliminating cost overruns on rental equipment throughout the project and cost savings of circa $1,000,000 during the six-month drilling campaign.
Assessment of Reservoir Properties using Applied Rock Physics & Seismic Inversion for Near-Field Exploration in a Niger Delta Field
Authors: Adesun Julius , Olajide Olanike , Ekesiobi Chidi , Ogunjobi Abidoun , Ishola Kehinde 
Published: July 2019

Abstract
A quantitative seismic interpretation (QSI) approach in assessing reservoir properties of a near-field exploration discovery is presented.
This approach demonstrates the integration of rock physics model and seismic inversion to determine the lateral extent of the reservoir complex, improve the understanding of geometry and connectivity of the reservoir sands encountered in this field; and improve confidence in estimates of the resource base.
An integrated interpretation approach that incorporates seismic and well log data sets, together with available relevant reports is adopted to reduce interpretation risk inherent with the study location. The hydrocarbon bearing reservoir sands were characterized, based on their elastic rock properties responses, to predict reservoir parameters for reservoir architectural delineation from seismic data volume. The results provide insight to address subsurface uncertainties associated with reservoir connectivity, and future infill well count determination for production optimization and possible reserves addition.