bluuebunny/crossref_metadata_2025_split huggingface dataset:
A Model to Determine the Effect of Pore Pressure and Fracture Gradient on Stuck Pipe Management
Authors: Boniface Oriji. A. , Marcus N. M. 
Published: July 2015

Abstract
Estimation of pore pressure and fracture gradient is very important in achieving a successful drilling operation. With proper estimation of pore pressure and fracture gradient, the drilling engineers can design accurate mud density that can-balance and stabilize the formation pressure without fracturing the formation. Proper estimation will minimize washouts, kicks, lost circulation and stuck pipe. This paper is on a Model developed using Visual Basic and Microsoft excel applications to compute the mud hydrostatic pressure, pore pressure, overburden gradient, fracture pressure and the overbalance pressure from a real field drilling data in order to predict the possible depths were stuck pipes could occur. The results from the analyses showed that at the depths where the pressure difference between the mud hydrostatic pressure and the formation pore pressure was greater than 500 psi, the pipe would most likely get stuck while a negative overbalance showed a kick. Also, from the analyses, between 8,100ft to 12,300ft depth, the pipe was freed from sticking and there was no kick because the hydrostatic presssure between these depths balanced accurately with the pore pressure.(overbalance less than 500psi). But from 12,300ft to 12,700ft, there was a kick because the formation pore pressure was quite higher than the hydrostatic pressure due to the abnormal pressure zone encountered. This situation could be managed by increasing the mud weight while maintaining a pressure overbalance less than 500 psi and mud hydrostaic pressure less than the fracture pressure at the same time. However, from 14,800ft and above, there was pipe sticking because the pressure overbalance was higher than 500 psi as a result of high mud weight. This model provides a platform for Well Engineers to detect the zones where kicks are likely to occur and the zones where the pipe could get stuck thereby effectively reducing losses resulting from down time caused by stuck pipes and fishing operations.
IPSM Plays Key Role in Maximising Oil Production and Minimising Gas Flare in the Re-opening of A Swamp Field in Niger Delta
Authors: Obakhena O. Femi , Nnanna Erasmus , Wakama Miebaka , Linus Nwoke 
Published: July 2015

Abstract
FEDA field is a medium-sized, step faulted anticline located in the coastal swamp area of the Niger Delta. The field is located about 70km south-west of Port Harcourt, Nigeria and has produced approximately 126MMstb of oil and 127Bscf of associated gas. The field has been developed with 9 wells (18 strings) with one well abandoned. Production from the wells is maintained by natural flow supported by a strong aquifer drive. The field was shut down for about 5years between 2008 and 2013 due to integrity issues with the trunk line. As at 2008 before the field was shut down, it produced 4.8Mbopd from 3 wells (5 strings). In 2010, a new trunk-line was commissioned which led to the re-opening of all the fields in the Swamp area including FEDA. However, there were various challenges that needed to be addressed before the flow station could be re-opened. One of such issues was the availability of gas to run the Low-Pressure, (LP) compressor, given its turn-down volume and due to restriction placed by the new flares-down policy being championed by SPDC.
In order to solve this problem, an Integration Production System Model (IPSM) was constructed. The model was calibrated ensuring accurate split between low pressure and high pressure gas streams which is not often considered in conventional IPSM analysis. The second issue was to consider the best scenario that would lead to optimum net oil production with the least volume of flared gas during compressor downtime in order to minimize production deferment.
The key outcome of the project is that accurate calibration of IPSM model can unlock asset deliverables and guide operations towards optimum oil production. This paper presents the results of an innovative use of the PETEX IPM to determine the accurate volume of low-pressure gas for re-start of an oil flow station in Niger Delta. The objective was to ensure that produced gas was not flared and that the volume of associated gas would be sufficient to operate the compression facility efficiently.
Deploying Continuous Improvement Methodologies to Improve Efficiency: A Way of Responding to Emerging Industry Challenges
Authors: Mustapha Adetoun , Umeh Nnaemeka , Adepoju Akeem 
Published: July 2015

Abstract
Local and global headwinds such as shrinking conventional oil reserves, environmental challenges, complex commercial frameworks; stricter regulations, higher production costs and drop in oil price continue to prevail in the oil and gas industry in recent times. In response to these challenges, the industry players (National and International E&P companies, Marginal Field Operators, Service Providers etc.) are constantly seeking ways to optimize operations and cash flow. This thus presents opportunities for the deployment of Continuous Improvement (CI) methodologies such as Lean, Six-Sigma as well as the recent development in the last few years that combines Lean and Six-Sigma to create “Lean Six Sigma”, to remove “wastes” (non-value adding activities) from processes and improve overall performance in business delivery.
While Lean focuses on removing non-value adding activity, aligning production with customer requirements and thus streamlining and optimizing process efficiency, Six-Sigma focuses on reducing process variation by delivering products at lower cost with improved quality and reduced cycle time. The application of the “Lean Six Sigma” is increasingly becoming a panacea for maintaining efficiency at all levels and driving operational efficiency in the industry. Continuous improvement not only makes good business sense but also improves job satisfaction.
This presentation will share what “wastes” look like in the oil and gas business, proffer ways we can spend less for more and share lessons learnt from deployment of continuous improvement in Shell Nigeria.
The Seamless Startup of the Ofon Phase 2 Project: A Demonstration of TOTAL's Strong Commitment to Eliminating Continuous Gas Flaring In Nigeria
Authors: Kue Yeghenee , Hyest Emmanuel , Darque Philippe , Sabally Lamin , Odemudia Abel 
Published: July 2015

Abstract
In the year 2000, TOTAL had announced that it would no longer continue routine flaring of associated gas on new oilfields development; and will make maximum efforts to stop continuous flaring on all existing installations. In 2004, TOTAL joined the Global Gas Flaring Reduction Partnership, A World Bank Initiative committed to reducing global gas flaring. The resolve of TOTAL's commitment to eliminating continuous gas flaring on all of its installations became overwhelming that between 1998 and 2005, TOTAL had reduced gas flaring by 40% despite, strong production growth within the same period.
In 2014, TOTAL set the objective to cut associated gas flaring by 50% from the 2005 baseline. Covered in this objective is the elimination of gas flaring on OML 102 - Ofon Oilfield, Nigeria; for which the Ofon Phase 2 Project have been endorsed and expected to achieve alongside other objectives. The project was scheduled to take off seven years after the phase 1 development which achieved its first oil in December, 1997 with no facilities for the utilization of the produced associated gas. Continuous gas flaring thus became unavoidable and thus served as the only way to safely dispose of the unwanted associated gas produced together with crude oil.
The eventual completion and realization of the seamless startup of Ofon phase 2 project, achieved in a context of high levels of local content coupled with the implementations additional energy efficient systems aimed at reducing global warming and energy consumption together is a clear demonstration of TOTAL's resolve to the sustainable development of the Niger Delta and the elimination of continuous gas flaring in Nigeria. In full compliance with Nigerian law, TOTAL has now eliminated gas flaring on OML102 – Ofon Oilfield. The elimination of gas flaring on the Ofon oilfield is also a significant milestone for TOTAL's environmental targets as it represents a 10% reduction in the Group's E&P flaring.
This paper presents the strategies and plans that were successfully implemented on the Ofon phase-2 project, which thus led to the realization of the seamless startup and consequently cascaded to the elimination of continuous gas flaring on the Ofon Oilfield Complex. The actions that were taken to drastically reduce the duration of the first oil startup which significantly reduced the initial startup flaring are also presented.
Case Study: Planning and Execution of a Subsea Hpht Well in the Niger-Delta
Authors: Nwagu Chike 
Published: July 2015

Abstract
Addax Petroleum Nigeria operates the OML-126 and 137 blocks in Nigeria. These are adjacent oil and gas blocks, located in the Niger-Delta region offshore. The close proximity of these blocks, and their similarity in terms of reservoir formation, means drilling activities in these blocks have had similar experiences. Past exploration wells targeting deep reservoirs in the blocks have experienced well control incidents resulting in the loss of millions of dollars due to the loss of several Bottom Hole Assemblies (BHAs), the loss of the wellbores and consequentially the premature termination of the projects. These well control issues were largely due to the pore pressure uncertainties in these blocks, which made it difficult to determine and plan the appropiate mud weights, required for the high pressures of the deep reservoirs.
The Star-6 (ST-6) well was a subsea High Pressure High Temperature (HPHT) exploration well, which was successfully drilled by Addax Petroleum Nigeria between September – October, 2014. The well is located in the OML-126 block.
Despite the short time frame for planning the well, with a range of possible pressures and temperatures, the drilling and exploration teams worked together to maintain safety and performance, and to overcome various logistical and operational challenges. The success of the well can largely be attributed to; the detailed well engineering planning, successful implementation of lessons learned from past exploration drilling activities in the area and utilization of industry recommended drilling practices.
This case study, takes a look at the different stages of well planning and actual execution of the ST-6 well that led to the drilling by Addax Petroleum Nigeria, of the first successful exploration well to date that met all its objectives in the OML-126 block.
Economics of Heat Loss Material Design in Transportation of Stranded Gases as Hydrates
Authors: Dosunmu Adewale , Udoh Nse-Obong , Ekeinde Evelyn , Anyanwu Chimaroke , Okoro Emeka 
Published: July 2015

Abstract
The Transportation of gas as hydrate with time is a function of the nature of the Hydrate carrying material of which when poorly designed can lead to loss of gas due to untimely re-gasification and hinders profit making. It is on this note that after the production of hydrate with natural gas, the ability for the Hydrate to reach its final point without on-transit re-gasification is seen as to be a function of the nature of the carrier material designed. In this study a robust software, HYGAS, has been developed to analyse the economics of the newly designed (heat loss) carrier model for transportation of natural gas by means of hydrate. Key parameters including the flow rate of the feed gas, abandonment rate and decline rate were considered. Also, the fiscal Parameters like the Gas price, Inflation rate, Royalty are considered. Finally, the CAPEX, OPEX, Depreciation and income tax rate are also taken into consideration during the designing. From the design, it is observed that at 0% discount, Internal rate of returns (IRR) or breakeven will be at nine years to come and at 15% discount rate, the IRR or Breakeven will be at seven years to come. The program at various discount values inputted can continue to give corresponding breakeven until a Most favorable condition can be met. Hence, Profit maximization can be attained.
Deployment of Remotely Operated Aerial Vehicles: Managing Asset Integrity in the 21st Century
Authors: Asiodu-Otughwor Isioma , Akhibi Osemhen , Aja-Onu Uchenna 
Published: July 2015

Abstract
Drones have found applications as toys, military equipment and parcel delivery services. Deploying Remotely Operated Aerial Vehicles (ROAV) has enabled new exciting frontiers to be broken in the upstream and downstream sectors of the industry. ROAVs are unmanned light-weight aircrafts that are remotely controlled and often kitted with instruments and cameras for diverse use-cases. Attaching a high definition camera converts the vehicles into data gathering systems that can work in remote, dangerous and hazardous environments.
As part of the Shell Group's technology replication initiative, the use of ROAV technology for Flare inspection is being adopted as part of SPDC's Asset Integrity Inspection procedure. The traditional inspection method, typically scheduled as a Turn-Around task, requires a shutdown of at least 3 days to allow for extinguishing of the flare, cooling down, and ascent of inspection personnel sometimes with rope access. Findings from the visual inspection of flare nozzles and stacks serve as input for maintenance and engineering work planning in future Turn-Around activities. A Non-Associated Gas (NAG) plant, a swing producer for a LNG facility, was selected as first deployment for this technology's application in SPDC.
This first deployment at the selected asset clearly demonstrates the following benefits; Elimination of working at height, Maintain safe distance from operating asset, Increased facility uptime and reduced deferment/interruption of operations. Other benefits include reduced cost to perform versus traditional methods (cranes, helicopters, scaffolding, and binoculars), shorter setup and faster inspection time, clear representation of asset condition using visible and thermal imagery and better planning of maintenance and turnarounds, especially in Life Extension programs. The application of this technology presents an innovative tool for asset integrity management with seamless data acquisition and storage which can be trended for condition monitoring application. It can be also used to inspect structures like masts, under-decks of offshore platforms, chimneys and tanks
Improved Data-driven Models for Forecasting Production Performance with Uncertainty Analysis
Authors: Ladipo O.. , Ogbe David O. 
Published: July 2015

AbstractData-driven analytical models are important tools employed in the petroleum industry to forecast production rates and reserves of petroleum assets. Studies have shown that existing rate-forecasting models project future performance trends by averaging the observed production history data with little or no preferential consideration of the influence of the trends of most recent historical production data. It is also understood that existing empirical data-driven rate forecast models do not account for the uncertainties involved in such future predictions.In this work, new statistically-based data-driven models for production performance forecasting are developed. These models forecast future production performance trends using statistical-exponential smoothing of the historically-observed data, attributing more weights to the most recent historically-observed performance trends. Both linear-exponential and double-exponential smoothing algorithms were considered in the study. The uncertainty analysis of these predictions is evaluated using the history-fit errors derived from the observed data and fits to the history. The models’ accuracy depends on the segment of the observed historical data selected for the initial data fitting and the trends of most recent historical production data—the tail end of the observed data. The application of the proposed statistically-based data driven models was demonstrated on several data sets. The results obtained from the proposed data-driven models compare favourably with the base forecasts derived from existing models such as the Arps’ Decline Curve Analysis techniques. The major advantage of the proposed models over existing models is that predicted forecasts include a range of possible performance trends honouring the observed production history with the associated probabilities and confidence intervals. The major contribution of this work is that coherent statistically-based models have been developed for forecasting production rates and reserves of petroleum assets with uncertainty analysis.
Strategy For Setting Up A Successful Drilling Bits Performance Contract
Authors: Oikelomen S. B. , Ogunnoiki J. O. , Iloabachie T. U. , Oboarekpe B. A. 
Published: July 2015

Abstract
This paper defines the strategy for setting up a successful Drilling Bits Performance Contract in the oil & Gas industry. Contrary to the traditional and common type of drilling bits agreement that promises payment for bits usage irrespective of performance, this performance based contract instils the required motivation in the bit application engineer to actively participate in upfront well planning and use a risk based approach to provide the best bit that would deliver exceptional results.
The drill bit is comparatively a small cost item in the drilling assembly. An expensive 8-1/2” PDC bit might cost about US$50,000. However, when it fails, the cost of recovery might vary widely from US$0.3 – 3 million; considering a simple remedial action such as tripping out of hole for bit change to losing bit cones in hole, fishing, plug back and side-track operations. In the traditional form of drilling contract, the bit supplier gets paid for all bits supplied and used irrespective of the bit performance, while the operating company bears all the risk. The performance based contract supports a shared ownership of the drilling operation and the associated risks.
In setting up a performance based contract, it is customary for the bits contractor to provide a long list of exceptions on why the contract may not be workable. Suppliers would usually want to walk away from investigating root causes of bit failures and ascribed the causes of failures to external factors like drilling practices, directional drilling equipment, driller's experience, information on lithology, et cetera. This paper will provide information on how to resolve such exceptions and set up a workable performance based contract.
Optimizing Hydraulics For Drilling Operations
Authors: Ugochukwu Okoli 
Published: July 2015

Abstract
Hydraulic modelling is an integral part of drilling operations, thus its importance for the efficient delivery of a wellbore cannot be over emphasized. The standard API methods for drilling fluid hydraulics assume either Power law or Bingham Plastic, these models provide a simple way of estimating required parameters for efficient drilling operations, but for conventional wells. These models are sometimes not accurate when used to model the hydraulics of more difficult wells.
When drilling fluid is circulated, pressure drop takes place due to friction between the fluid and the surface of the stand-pipe, rotary hose, swivel, Kelly, drill-pipe, drill-collar, drill-bit, and the annulus between the drill-string and the open hole or casing. This generates a total frictional pressure drop in the hydraulic circuit called the Stand Pipe Pressure (SPP). The Equivalent Circulating density (ECD), which is generated from annular pressure losses, needs to be predicted correctly to ensure that the fracture gradient of the formation to be drilled is not exceeded, as there will be losses of the drilling fluid into the formation and potential wellbore instability problems.
The paper discusses seven (7) rheological correlations/equations from studies (Robertson-Stiff, Casson, Carreau, Sisko&Willamson, Hershel Buckley, Cross and Modified Bingham Plastic) which have been used in different conditions to simulate and predict the parameters required for efficient hole cleaning operations. It then highlights the magnitude of failure that occurs when simple hydraulic correlations/models are used for complex wells and very viscoplastic fluids.
The paper compares and discusses the variation with actual results when the Bingham Plastic, Power, Hershel Buckley and Robertson Stiff models are used to model fluid hydraulics. It proposes that the correct hydraulics of a particular well depends on the nature of the reservoir and bottomhole conditions, as the data from an offset well might not be representative of a target well. Thus it is required that an engineer should run different simulations using different hydraulic models and then compare with the actual data during operations. The difference between the simulated and actual can be used as the fudge factor to further optimize the hydraulics for other hole sections or wells with similar configurations, if the best fit hydraulic model is unavailable in the simulator.
Flared Gas To Sellable Products: Total Gas Consumption Technology Solution For Stranded Gas Fields In The Niger Delta
Authors: Fagbami Debo , Obofukoro Ejiri , Maduike Basil , Ekpeti Egoyibo 
Published: July 2015

Abstract
The negative impact of increased industrialization and urbanization has been a source of major concern to industrial stakeholders. More specifically, crude oil exploration and production has contributed largely to environmental degradation. Associated gas produced alongside crude oil production, which is being flared all over the Niger Delta has been a perennial source of environmental pollution. The attendant impact on the quality of life of the local population can also not be over emphasized. Flared gas emits carbon monoxide into the environment as well as warm up the environment, thereby contributing to the global warming scourge. It has been recorded that over 17 billion cubic meters of natural gas is flared annually around the Niger Delta region, a volume, which equates to about a quarter of the current power consumption of the African continent. There is an urgent need to devise techniques and methodologies to end gas flaring and preserve our environment. One such way is the conversion of associated gas to products of value. This paper examines the utilization of the gas to products/liquid technology to help combat an age-long problem while highlighting the socio-economic benefit of the solution. A practical case study of a total gas consumption technology solution is described with recommendations for future work and practice.
A Demonstration Model of a Mobile Expert System with Augmented Reality User Interface Supporting M-28 Aircraft Maintenace / Prototyp Przenośnego - Ekspertowego Systemu Z Rzeczywistoścą Rozszerzoną Do Obsługi Samolotu M-28
Authors: Golański Piotr , Perz-Osowska Małgorzata , Szczekala Marek 
Published: July 2015

Abstract
The paper discusses the problem of supporting aircraft diagnostic and maintenance processes. A possibility of usage of modern technologies, that could facilitate aircraft’s maintenance procedures and increase safety of their service, is presented. A usage of a mobile device, with implemented expert system and user interface based on augmented reality technology, is suggested. Proposed system structure is presented in the paper. Also, a possibility of usage of such a system is demonstrated on M-28 aircraft simulator