bluuebunny/crossref_metadata_2025_split huggingface dataset:
Pilot-Scale Evaluation of Natural-Gas-Based Foam at High Pressures, Temperatures
Authors: Carpenter Chris 
Published: August 2021

This article, written by JPT Technology Editor Chris Carpenter, contains highlights of paper SPE 201611, “A Pilot-Scale Evaluation of Natural-Gas-Based Foam at Elevated Pressure and Temperature Conditions,” by Griffin Beck, Swanand Bhagwat, and Carolyn Day, Southwest Research Institute, et al., prepared for the 2020 SPE Annual Technical Conference and Exhibition, originally scheduled to be held in Denver, 5–7 October. The paper has not been peer reviewed.
The complete paper presents recent results from a rigorous pilot-scale demonstration of natural-gas (NG) foam over a range of operating scenarios relevant to surface and bottomhole conditions with a variety of base-fluid mixtures. The NG foams explored in these investigations exhibited typical shear-thinning behavior observed in rheological studies of nitrogen- (N2) and carbon-dioxide- (CO2) based foams. The measured viscosity and observed stability indicate that NG foams are well-suited for fracturing applications.

Test Facilities
Two test facilities were used to explore properties of NG foams at a variety of relevant operating conditions to determine whether NG foam is a suitable alternative to typical water-based fracturing fluids.
Pilot-Scale Foam-Test Facility. The pilot-scale foam-test facility (PFTF) is a single-pass pilot plant used to generate and characterize foams at conditions relevant to surface and reservoir conditions. The facility is capable of generating aqueous and oil-based foams using a variety of gases for the internal phase [e.g., methane (CH4), N2, and CO2]. Foams can be characterized at pressures up to 7,500 psi and temperatures up to 300°F. A key benefit of the PFTF is that it can be used to demonstrate new or challenging foaming processes before large-scale or field demonstrations. Further, these processes can be evaluated at conditions relevant to the final application.
The test facility consists of three subsystems: a base-fluid system to pressurize and heat the liquid/viscosifier/surfactant mixture, a gas system to pressurize and heat the liquefied gas stream, and the foam test sections to measure various fluid properties of the NG foam.
Laboratory Foam-Test Facility. Tests performed on the PFTF were limited to foams generated with pure CH4 and tap water. Additional laboratory tests were conducted to investigate the effects of multiconstituent natural gas mixtures and produced water on foam stability. For these tests, the aqueous base fluid for the foam half-life and foam rheology experiments was prepared from either de-ionized water, tap water, or a synthetic produced water based on a water sample from the Permian Basin. Foam fracturing fluids also typically contain a gelling agent and a foaming agent. The gel was prepared by slow addition of guar to a stirred water sample followed by 30 minutes of mixing to ensure complete hydration. The foaming agent was added and stirred in gently. Three foaming agents were used in this study: anionic Foamer A, nonionic Foamer B, and zwitterionic Foamer C.
Optimized Technical and Commercial Strategy for Marginal Field Re-Entry – A Case Study
Authors: Onwuemene Onyeka 
Published: August 2021

Abstract
This paper examines an optimized strategy and approach for executing a marginal field re-entry in the face of harsh global economic realities in the oil and gas sector.
With dwindling and depressing oil prices driven by demand & supply volatility with root causes traceable to some factors such as the prevalent health pandemic, clamor for green energy, climate change discussions, geopolitics etc, the operating model for oil companies will need to drastically change to reflect current realities.
Due to rapid global urbanization and increasing population amongst other factors, there is a corresponding huge appetite for oil to meet energy demands. This has led to exploration in unconventional terrains, utilization of the full extent of primary and secondary recovery mechanisms to attain high RFs in already producing fields and in some extreme cases, the development of marginal fields.
In the Niger Delta area of Nigeria, marginal fields usually given up by Oil majors or abandoned following production exigencies and government laws are acquired and operated by indeginous companies. These indigenous players look for the most cost-effective means to produce these assets as it becomes the only way to make profit.
A case study for field re-entry in the Niger Delta, which emphasized relatively/comparatively reduced capital outlay dependent on the technical approach is examined. Lessons learnt are drawn to aid enlightened go-forward actions and that will ensure a go-to template for similar future marginal field re-entry projects.
Reducing Accidents Through the Implementation of the Minimum Industry Safety Training for Downstream Operations Mistdo in the Nigerian Oil and Gas Industry
Authors: Edem Michael , Nwankwo Okechukwu , Muku Jennifer , Usman Fatima , Ike Chidi 
Published: August 2021

Abstract
The Department of Petroleum Resources (DPR), the Petroleum Regulatory agency of the Nigerian oil and gas industry is mandated by law to investigate accidents in the industry. Data obtained from the oil and gas accident database from the Department of Petroleum Resources shows that accidents in the downstream sector contribute about 70%, when compared to the upstream sector. One of the reoccurring root causes from investigations point to administrative barrier failure – which is a lack of training and re-training of staff in the downstream sector on workplace safety. Against this background, the DPR introduced the Minimum Industry Safety Training for Downstream Operations (MISTDO) as part of the Safety Audit Clearance policy launched to drive safety in the downstream sector. MISTDO is a basic safety training which must be undertaken by all personnel working in the downstream sector of the Nigerian oil and gas industry. This paper reviews the recorded accidents that have occurred in the downstream sector between 2014 – 2019; examines the MISTDO courses for the various workers in downstream facilities; analyses the MISTDO tripartite model (Training provider, Operator and DPR) adopted; the effects of implementation of MISTDO and concludes with the value additions of the MISTDO program to the industry.
The Environmental Accounting: Experiences From Overseas and Solutions for Marginal Field Operators in Nigeria
Authors: Oruwari Humphrey Otombosoba 
Published: August 2021

Abstract
Marginal oil field operators have been bedeviled by several challenges since its inception, among which are financial, technological, socio-political, ecological and environmental issues. The study examined how marginal oil field operating in Niger Delta region of Nigeria could integrate and incorporate environmental accounting for managing the environmental performance of their businesses efficiently. Using literature review and case study, the study revealed that at present, environmental accounting is gradually being implemented worldwide. It is the duty of companies to apply environmental accounting to the lives of individuals. The study summarizes some key points regarding environmental accounting, the introduction of environmental accounting in some countries around the world and demonstrates some challenges in our country's application of environmental accounting to provide some solutions to boost the application of environmental accounting to marginal oil field operators in Niger Delta. The study recommends that environmental accounting will enhance the operations of marginal oil field in Niger Delta region.
Optimization of the Turnaround Time and Quality of Production-Screening Tests in Offshore Fields – Some Case Studies
Authors: Eyitayo Stella I. , Lawal Kazeem A. , Abdullahi Ibrahim , Matemilola Saka , Akadang John , Anyanwu Victor , Ainoje Bernard , Alabi Tunde , Owolabi Segun 
Published: August 2021

Abstract
Production-screening test (PST) is performed on a reservoir drill-in fluid (RDIF) prior to running any component of the lower completion assembly that is vulnerable to plugging. This is applicable in open-hole completions in which wire-wrapped production screens are deployed. The key objective of a PST is to reduce the risk of plugging key completion components, such as production screens, during subsequent flow back. Hence, a PST increases the chance of preserving well productivity (or injectivity), ultimate recovery and project economics. However, conducting and achieving PST-quality RDIF in offshore fields can be cumbersome, time-consuming, and expensive, yet the quality is not guaranteed.
This paper presents the formulation, implementation, and results of a simple strategy to reduce the turnaround time and costs of achieving PST-quality RDIF for applications in offshore fields. Employing a combination of on-the-job assessment, empirical data and expert opinions, the strengths and weaknesses of onsite versus offsite (onshore) options of preparing PST-quality RDIF for offshore operations are evaluated.
As a case-study, empirical data from the execution of both onsite and offsite options for an example field are employed for the evaluation. Results of simple cost-time-benefit analysis underscore the robustness and competitiveness of preparing the PST-quality RDIF offsite and transporting same for subsequent test validation and application on the rig.
The results of these empirical examples show that the offsite option yields about 75% cost-saving relative to its onsite counterpart. In addition to cost saving, other incremental benefits of the former include (i) significant reduction in rig time and personnel; (ii) improved RDIF quality; and (iii) higher chances of preserving well performance and economics. To increase the success rate, residual risks of the preferred offsite option are outlined, and relevant mitigations provided.
Gravity Drainage System: Investigation and Field Development Using Geological Modelling and Reservoir Simulation
Authors: Ezeaneche Obinna Somadina , Madu Robinson Osita , Oshilike Ishioma Bridget , Athoja Orrelo Jerry , Onyekonwu Mike Obi 
Published: August 2021

Abstract
Proper understanding of reservoir producing mechanism forms a backbone for optimal fluid recovery in any reservoir. Such an understanding is usually fostered by a detailed petrophysical evaluation, structural interpretation, geological description and modelling as well as production performance assessment prior to history matching and reservoir simulation.
In this study, gravity drainage mechanism was identified as the primary force for production in reservoir X located in Niger Delta province and this required proper model calibration using variation of vertical anisotropic ratio based on identified facies as against a single value method which does not capture heterogeneity properly. Using structural maps generated from interpretation of seismic data, and other petrophysical parameters from available well logs and core data such as porosity, permeability and facies description based on environment of deposition, a geological model capturing the structural dips, facies distribution and well locations was built. Dynamic modeling was conducted on the base case model and also on the low and high case conceptual models to capture different structural dips of the reservoir.
The result from history matching of the base case model reveals that variation of vertical anisotropic ratio (i.e. kv/kh) based on identified facies across the system is more effective in capturing heterogeneity than using a deterministic value that is more popular. In addition, gas segregated fastest in the high case model with the steepest dip compared to the base and low case models. An improved dynamic model saturation match was achieved in line with the geological description and the observed reservoir performance. Quick wins scenarios were identified and this led to an additional reserve yield of over 1MMSTB.
Therefore, structural control, facies type, reservoir thickness and nature of oil volatility are key forces driving the gravity drainage mechanism.
A Simple Strategy For Subsurface Delivery of Effective Development Wells – Field Examples
Authors: Salako Abdulganiyu , Pelemo Bosun , Otubanjo Modupe , Lawan Zainab , Olushoga Elizabeth , Eyitayo Stella , Ukaonu Cyril , Lawal Kazeem A. , Matemilola Saka , Owolabi Segun 
Published: August 2021

Abstract
Well delivery is an expensive scope in the exploration and field development process. Among other drivers, an ideal well must be delivered safely while achieving top-quartile performance on cost, schedule and business objectives. However, delivering an ideal well amid subsurface uncertainties and tightening budgets is usually challenging.
As part of the drive for continued value creation, this paper presents an empirical process-improvement initiative for de-risking and optimizing the landing of the drain-hole sections of highly deviated wells amid subsurface uncertainties and at minimal costs. A review of the conventional procedure for executing subsurface scope of the delivery of development wells has been accomplished. The review takes advantage of a combination of recent experiences in delivering four horizontal development wells in an offshore field in the Niger Delta, in addition to a catalogue of available knowledge and best practices from other fields and operators.
This review culminates in an improved well delivery optimization process and practice. In addition to promoting operational HSE excellence, it increases the chance of delivering an ideal well, including the mitigation of a subsurface-related non-productive time (NPT) and other related costs. As a complement to the practice, a simple workflow is provided to aid robust decision-making and facilitate applications in practice. For completeness, relevant examples are included to demonstrate the applicability of this new process.
The Implementation of Offshore Safety Program OSP in Nigerian Oil and Gas Industry- A Performance Assessment
Authors: Nwankwo Okechukwu. K , Muku Jennifer. S , Ogunbona Oladipo G. , Ike Chidi. B , Amosa Dr. Mutiu. K , Ogionwo Ebipador 
Published: August 2021

Abstract
The Offshore Safety Permit (OSP) Program is the Personnel Accountability System, being utilized by the Nigerian Oil and Gas Industry Regulator, in line with global best practices to manage the details of over 40,000 oil workers registered to work on offshore and swamp facilities and track their movements to-and-fro such facilities. The Program was introduced in 2012 to standardize requirement for personnel travel to offshore and swamp locations and to eliminate issues such as: non-compliance with mandatory competency and safety training; non-compliance with medical fitness to work requirement; unauthorized extended stay on facilities at offshore/remote location; inaccurate documentation of personnel movement to-and-fro facilities at offshore/remote location leading to delayed/wrong incident reporting. This paper examines, through the review of the OSP policy, Guidelines and database, the value addition of the program since its inception., detailed and insightful discussions are made on the importance and potentials of the OSP program as a simple but integral policy and planning tool in managing risks, enhancing collaboration and improving safety and emergency services in Nigeria's oil and gas industry.
Understanding Oilfield Scale Deposition and Inhibition Mechanisms for Optimum Management: A Review
Authors: Adegoke Samuel Oluwafikayo , Falode Olugbenga Adebanjo , Nwankwo Princess Christiana 
Published: August 2021

Abstract
Oilfield scales are crystalline minerals made up of Na, K, Mg, Ca, Ba, Sr, Fe, Cl from produced water that can precipitate out in the reservoir, well, pipelines and process during the production and transportation of oil and gas. These precipitates can deposit as a result of thermodynamic and/or chemical changes and pose costly flow assurance issues to the oil industry. Several factors have been identified to be responsible including temperature, pressure, ionic strength, pH, evaporation, bicarbonate anion, super-saturation and contact time and water chemistry. Attempts to solve this problem in the past have focused mainly on the use of chemical inhibitors and the most accepted mechanism of scale inhibition is squeeze injection method. While adsorption and retention of scale inhibitors on rock formations needs more research, there had been improvement to better ways of ensuring adsorption and precipitation through nanotechnology including the use of nano-carbon enhanced squeeze treatment (NCEST). The uses of these conventional inhibitors have been found to be toxic to the flora and fauna in biotic communities during water disposal. In order to reduce the environmental burden caused by these conventional solutions and still manage the problem effectively, greener solutions have been proposed. This review x-rays the mechanisms of scale precipitation and deposition, evaluate the solutions that have been provided in literature based on efficiency, economics and environmental impact and propose guidelines to field operators in selecting optimum solutions.
Integrated EOR Screening in a Marginal Oil Field Environment
Authors: Uche Chukwunonso , Esieboma Samuel , Uche Jennifer , Bukar Ibrahim 
Published: August 2021

Abstract
An evaluation of potential EOR processes applicable in the marginal oil field operation of the Niger Delta region is presented. Technical feasibility, process availability, oil recovery potential, and other uncertainties and risks associated with exploitation of enhanced oil recovery technique in a marginal oil field environment are being assessed. Few Enhanced oil recovery processes, namely polymer flooding, chemical flooding and microbial EOR (MEOR), are considered for possible application in this marginal oil field. The objective of the screening study is to evaluate and rank the EOR options and also select the most attractive method that will have to be further chased to a pilot test stage. Emphasis is strictly on a technical assessment of the incremental oil potential of each of the EOR methods and also identification of critical operational and logistical components of the entire process for their implementation in the offshore operating environment.
Recoverable volumes associated with EOR may be significant, but key project development and implementation challenges and extra cost elements must be considered in any EOR forecast for an effective EOR process ranking. Some of these concerns (e.g. Polymer/chemical supply, facilities requirements, and the impact of EOR on reservoir performance and wellbore integrity) may be significant enough to eliminate a method from being considered further and at that point the best EOR option that requires minimal cost exposure for achieving the best recoverable shall be considered.
Moreso, there is consideration of the quantity and quality of laboratory data that should support the viability of each EOR process being considered. This paper narrates the state of technical readiness for field implementation of each EOR method and identifies remaining work required to progress EOR process in this marginal oil field.
Hydrocarbon Volume Estimate Using Pseudo Steady-State/Pressure-Transient Principles in a Faulted Reservoir
Authors: Uche Chukwunonso , Uche Jennifer 
Published: August 2021

Abstract
The application of pseudo-steady-state and pressure transient response techniques to assist in hydrocarbon volume estimate is presented for a reservoir isolated from its main by a non-sealing fault. The techniques discussed in this paper utilized the pseudo steady state principle to determine the fault boundary behavior dominated flow regime of an oil well which has produced for over eight years in a marginal field of the Niger Delta environment. The material balance technique which utilized accountability of fluid withdrawn/injected and energy conservation principles within the pseudo steady state boundary dominated flow was used alongside with the pressure transient analysis to validate this oil in place number. Seismic attributes was also used to predict the geometry and distribution of the sand based on the conventional seismic interpretation. The seismic attribute analyses clearly show the geometry and spatial distribution of the reservoir sand bodies. Hence, understanding a pseudo steady state dominated regional flow time in a faulted reservoir plays a key role in the management and development of reserves in a marginal field operation.
A Novel Approach to Predicting Combustion Emission Using Ambient Air Quality Parameters in Onshore Eastern Nigeria
Authors: Omion Osemanre Ossy , Maduewesi Chioma , Chukwu Emeke 
Published: August 2021

Abstract
The paper aims to estimate the tCO2e from flare stack sites in the Eastern zone of Nigeria and review air monitoring done at the flare sites with the objective of establishing a model for gas tCO2e emission and gaseous pollutants. It focuses on the South-Eastern region of Nigeria where oil and gas production are being carried out (Imo and Abia states). It zero-in on the hydrocarbon processing and handling facilities (flowstation) and the gas flared volumes. The study was carried out using representative data from an onshore flowstation in Eastern Nigeria. The data consist of gas flared volumes from year 2013-2017 and ambient gaseous emission from air quality report done on the same location. Univariate regression and correlation using Excel were carried out on yearly average ambient air quality parameters (VOC, NOx, CO, SOx, CH4, SPM, NH3, H2S) to check the statistical significance of each parameter as an independent variable and calculated tCO2e as the dependent variable. Excel Muti-variate linear regression method was then used to generate a predictive model for tCO2e and gaseous emission parameters. It presented a relationship between the emission from flared gas and air quality index.
Design and Fabrication of a Carbondioxide Gas Leak Detection System for Oil and Gas Facilities
Authors: Amaobichukwu Chibuzor 
Published: August 2021

Abstract
In the recent past, there has been cases of carbon dioxide leak related incidents and casualties. Carbon dioxide has been recognized as a significant worthy hazard in the industrial environment for about 100 years. low concentrations of carbon dioxide are not harmful, but on a high concentration can affect the respiratory function and the central nervous system. This prompted the development of this carbon dioxide gas leakage detection system as a safety measure to reduce this risk. This carbon dioxide gas leakage detection is developed with an Arduino microcontroller and an MQ-135 sensor for a highly accurate and fast response system. The detection system incorporates an LCD Screen for displaying the status and level of concentration of the gas leakage, a buzzer as an alarm to give audio alerts, indicating and alerting users on the gas leakage, a number of LED lights to indicate the gas leakage status. The system also incorporates a GSM Module which sends SMS alerts and make calls to users during the gas leakage regardless distance. The Arduino microcontroller is programmed using embedded C++ language and all the peripherals connected to it through its pins. When the detector is in normal state, the LED light is lit on Green to show a normal range in concentration of gases and/or absence of a gas leakage. When there is gas leakage, the system transitions into a harmful state. The system displays the status of the gas leakage on the LCD Screen just as other LED lights light up in conjunction with an alarm buzz giving an audiovisual alarm to the monitoring mobile device. Also, the GSM Module sends out SMS alerts and calls to designated users regardless of their distance from the gas leak vicinity to notify them of the gas leak in order to take immediate action to control the gas leakage situation. The gas leakage detection is not only highly accurate but cheap and portable and can be used for industrial and domestic safety.