bluuebunny/crossref_metadata_2025_split huggingface dataset:
Impacts From Oil and Gas Produced-Water Discharges on the Gulf of Mexico Hypoxic Zone
Authors: Parker M. E. , Satterlee K. , Veil J. A. 
Published: December 2007

Abstract
Shallow water areas of the Gulf of Mexico continental shelf experience low dissolved oxygen (hypoxia) each summer. The hypoxic zone is primarily caused by input of nutrients from the Mississippi and Atchafalaya Rivers. The nutrients stimulate the growth of phytoplankton, which leads to reduction of the oxygen concentration near the sea floor. During the renewal of an offshore discharge permit used by the oil and gas industry in the Gulf of Mexico, the U.S. Environmental Protection Agency (EPA) identified the need to assess the potential contribution from produced water discharges to the occurrence of hypoxia. The EPA permit required either that all platforms in the hypoxic zone submit produced water samples, or that industry perform a coordinated sampling program. This paper, based on a report submitted to EPA in August 2005 (1), describes the results of the joint industry sampling program and the use of those results to quantify the relative significance of produced water discharges in the context of other sources on the occurrence of hypoxia in the Gulf of Mexico.
In the sampling program, 16 facilities were selected for multiple sampling-three times each at one month intervals--and another 34 sites for onetime sampling. The goal of the sampling program was to quantify the sources and amount of oxygen demand associated with a variety of Gulf of Mexico produced waters. Data collected included direct oxygen demand measured by BOD5 (5-day biochemical oxygen demand) and TOC (total organic carbon) and indirect oxygen demand measured by nitrogen compounds (ammonia, nitrate, nitrate, and TKN [total Kjeldahl nitrogen]) and phosphorus (total phosphorus and orthophosphate).
These data will serve as inputs to several available computer models currently in use for forecasting the occurrence of hypoxia in the Gulf of Mexico. The output of each model will be compared for consistency in their predictions and then a semi-quantitative estimate of the relative significance of produced water inputs to hypoxia will be made.
Ten Years of Experience With Stabberless Casing and Tubing Running Systems—A Safe Way To Save Time
Authors: Kinzel H. , Kiess C. , Redzal S. 
Published: December 2007

Abstract
Traditional casing or tubing running involves one crew member working thirty feet above the rig floor, secured to the rig only by a safety cable. The crew member performing this job is called the stabber and his work is the most physically demanding and potentially dangerous job in the casing crew.
In 1996 a system was introduced that allows stabberless running of casing and tubing strings. The system mainly consists of a hydraulically activated remote controlled arm, named the StabMaster that is mounted in the derrick and a remotely controlled set of a spider an elevator equipped with interlock and sensor systems. This system not only eliminates the job function of the stabber but it also allows much more precise stabbing-in of the connection because once the well center position has been found at the beginning of the job, it is memorized by the electronic control system. This minimizes delays due to cross-threading or damaged connections due to an out-of-center alignment of the joint to be stabbed-in.
Although the primary function of the Stabberless System was to enhance the safety, 10 years of running experience with over 100 installed StabMaster systems worldwide shows that this system is capable of reducing casing and tubing or riser running time considerably, without compromising safety.
The paper describes the components of the Stabberless System and presents results of studies that were made in various locations in the world showing that running times can be reduced between 20% and 30%. The studies show also, that there is a direct correlation between using the Stabberless System and a decreasing number of recordable incidents.
The Snorre A Incident 28 November 2004: Lessons Learned
Authors: Pettersen G. , Moldskred I. O. , Ytredal E. B. 
Published: December 2007

Abstract
Statoil has carried out a comprehensive analysis of the underlying causes after a gas seabed blow-out on the Snorre field in the North Sea. The Norwegian authorities have described the incident as one of the most serious ever to occur in the North Sea. The causal analysis is based on the "Pentagon model". The results show the importance of viewing the technological, organisational and human factors in conjunction in order to best understand the underlying factors and to draw up relevant, focused follow-up measures.
Risk-Based Design—A Comparison of the Agbami and Captain FPSOs
Authors: Haughie I. J. , Duncan L. 
Published: December 2007

Abstract
The Captain FPSO in the United Kingdom Continental Shelf (UKCS) and the Agbami FPSO in the Gulf of Guinea, are examples of two upstream FPSO oil and gas developments. This paper will highlight how these designs, which began from the same core design codes and standards, were optimized to mitigate the local health, environment and safety risks. This optimization was achieved through risk based design.
Efficient Computational Method For Casing String Design
Authors: Akpan H. O. , Kwelle S. O. 
Published: December 2007

Abstract
Casing design should place the economics in its vital spot not compromising the Maximum Load concept consideration. The attainable, optimum condition is to design casing to withstand these problem imposed loads for the minimum cost. If this is not designed for, but is experienced, the casing string can fail and its remaining life forfeited.
This research study presents a computer program for casing string design using Microsoft Visual Basic 6.0. The program is menu driven and has a user-friendly interactive interface. Other features are its automated analysis steps and common engineering units.
The results obtained when tested with two other commercial casing software like DRILLPRO V3.0 and a spreadsheet software by Landmark were satisfactory; hence can be used. This program has an additional features of determining the overall cost of the selected strings (in the program database), pore pressure/fracture gradient prediction as well as the number of sacks of cement for slurry design.
A Computer Programme For Gas Parameters Measurement (GPM +PLUS)
Authors: Ibelegbu C , Agbor E. , Egbe T. 
Published: December 2007

Abstract
As the economic importance of Natural gas continues to grow, gas well surveillance equally generates more interest to the petroleum Industry. The static and flowing Bottom-hole pressures must be known in order to predict the productivity or absolute open flow potential of gas wells. Often, these parameters are measured using down hole gauges method of gas well test. In Gas wells, down hole parameters could be estimated using mathematical expressions relating separator conditions and the configuration of the Piping system, instead of measured directly using Gas well Test procedure thus saving lots of dollars.
The conventional method of Gas parameter measurement include the iterative method, the Sukkar and Cornell method, Cullender and Smith method. Others are Crawford and Fancher and the Poettman method.
All these methods involve very long and cumbersome Iterative/look up procedures. This makes the job of the field men very tedious, especially when the unit system changes. Similarly, data integrity is not guaranteed and could mar the estimation of parameters because data is far from actual. These iterative/look up procedures are always simplified by field men at the expense of accuracy.
Engineering problems are now becoming complex that their effective solution requires the systems approach using computers. This research work presents a Microcomputer program for the estimation of Static and Flowing Bottom hole pressure in gas wells, using the iterative method, Sukkar and Cornell method and the Cullender and Simth method. It utilizes a user-friendly window/ dialog based Visual Basic program functional with adjustable unit system.
A Simple Approach To Modelling Gas Well Deliverability
Authors: Eme Vincent O. 
Published: December 2007

Abstract
The Petroleum industry has recognized the value of monetizing gas resources. The Nigerian Government has stated its desire to grow the gas business. Numerous gas projects are either being planned or in the execution phase. The objective of this paper is to present a simple screening tool for evaluating gas well performance.
Numerical simulation is expensive and time consuming. Analytical approach to predicting gas performance is needed as a screening tool. The three components to performance prediction are: Initial rate estimate, prediction of rate decline as reservoir pressure depletes, and prediction of reservoir pressure decline due to production.
This paper shows that the decline in gas rate for various tubing sizes (3 ½", 4 ½", 5-1/2", and 7") on a dimensionless or normalized scale is similar. The resulting relationship combined with the material balance equation for depletion drive reservoirs gives a method of predicting performance of gas wells. This method is adequate for most gas reservoirs except for those under strong water drives.
The proposed paper will present details of how to develop a deliverability model for gas wells from very basic data. The forecast from this model will be compared with a 3-D numerical simulation result. The results from this method are close to those obtained from 3-D numerical simulation.
Feasibility Study on Application of Multiphase Pumping Towards Zero Gas Flaring in Nigeria
Authors: Lastra Rafael , Johnson Ikouwem 
Published: December 2007

Abstract
With the application of multiphase pumping unprocessed well effluent could be boosted over long distances without need for separation of phases. The Nigeria Oil Industry stands to benefit immensely from this application in the area of economical eradication of gas flaring, a menace that has robbed the industry of about $6.8 MM everyday. The conventional means of transferring gas to the sales point, which is by separation and compression, is very expensive which has occasioned the incessant flaring of associated gas. This paper compares the economic benefits of using MPP over the conventional method. Revenue from gas sales would benefit both the Nigerian government and the operators. Flares extinction would assure cleaner environment and reduction in health hazards, which have benefits of a global dimension.
Incorporation Of Environmental Reviews Into Facility Design – A New Challenge In The Petroleum Industry
Authors: Ukwuoma Okechukwu , Ononuju Charles N. 
Published: December 2007

Abstract
Environmental issues are no longer of concern only in a few "smokestack" industries. Today all businesses, especially the petroleum industry, are affected by environmental challenges and attempts by government to regulate those challenges. The successful management of these concerns require increasingly sophisticated knowledge, planning and techniques. Certainly, environment and safety are too hot buzz words for the petroleum industry in this 21st century. Complying to more stringent regulations will be expensive and will dramatically change the economics of many oil field developments. This is a guaranteed growth area in the industry. The petroleum industry is producing more water per barrel of oil than ever before- and the trend will continue. As a result crude oil lifting costs will escalate and corrosion will become an even more vexing problem.
Flow lines and umbilicals represent the "life" and "control" of subsea satellite wells. When either fails or is damaged the well either ceases to produce, reinject or cause spillages.
It is virtually impossible for any industry project to be 100% environmentally safe. And the modification of an existing facility in order to comply with the regulations inherently limits the flexibility and unfortunately is too expensive. Therefore during the early stages of new facility design, ample opportunity exists to implement design modifications that reduce environmental risks, while complying with the regulations.
This paper identifies and details some proactive environmental step procedure for use during the early design phases of a new facility. Completing these steps will ensure that all environmental issues are addressed and that all opportunities to optimize environmental safety have been effectively defined and analyzed. Furthermore, successful implementation of this procedure will certainly result in a combination of environmental benefits and positive economic returns.
Validating Reciprocal Productivity Index Parameter And Reserves Estimates Using Classical RE Techniques
Authors: Ifeanyi Ezuka 
Published: December 2007

Abstract
Reciprocal Productivity Index (RPI) is graphical production analysis method that provides us with the technique/ability to estimate descriptive engineering parameters, such as permeability, skin, drainage area, and to generate production forecasts and reserves based on those parameters, without the cost of full numerical simulation or extended buildup tests.
The method's theoretical basis arises from the fact that traditional constant rate or constant pressure (potential) boundary conditions are sufficient, but that the necessary boundary condition only requires that the sandface transmissibility remain constant over time. With that difference, it is possible to accurately evaluate production histories, in which both the rate and pressure are varying over time, using traditional well testing methods.
The reservoir average pressure can also be evaluated from routinely available rate and flowing pressure production data, using an extension of this reciprocal productivity index method. Traditionally, reservoir average pressure could only be determined from an extended duration build-up test. This procedure generally tends to underestimate the pressure, due to practical limitations on shut-in times. In addition, an error in the reservoir average pressure determination results in an error in the computed skin for the well. However, this new procedure provides an independent evaluation of skin and pressure so that they are not dependent on one another. The theory for the method is in the appendix.
This paper explains how we used this technique to evaluate engineering parameters and validate the estimated reservoir pressure using reverse material balance.
Net-To-Gross Ratios: Implications in Integrated Reservoir Management Studies
Authors: Egbele Emmanuel , Ezuka Ifeanyi , Onyekonwu Michael 
Published: December 2007

Abstract
Geoscientists and reservoir engineers are very well acquainted with the terms "net-to-gross (NTG)" and "petrophysical cut-offs" or just "cut-offs". The significance of these terms is ultimately to define productive zones in the reservoir for hydrocarbon exploitation. However, there has been marked misunderstanding surrounding the usage of the term, net-to-gross and implicitly, the derivation of cut-offs which are limiting values used in expressing the net-to-gross ratio. While the geologist may be concerned with the pay for evaluating hydrocarbon-in-place and the ultimately the estimation of economically producible reserves, the simulation engineer is more concerned with fluid flow for pressure support in the reservoir1.
The significance of this paper is to consider the different cut-offs selection methods, the varying interpretation of net-to-gross ratios and the implications inherent in such methods. A case study from a field in the Niger Delta is also carried out to reveal the impact of such selection criteria especially in rocks with congenital weak hydraulic properties which cannot be excluded at geologic correlation stage2. The effect of cut-off parameters on oil-initially-in-place (OIIP) calculation was also investigated and a sensitivity analysis carried out on the petrophysical parameters to reveal the impact of the dynamically conditioned cut-offs selection on the petrofacies. Multiple Monte Carlo realizations were also employed to obtain probabilistic OIIP estimates rather than a single deterministic result.
Integration of Geology and Petrophysics for the Characterisation of a Sandstone Reservoir
Authors: Ekpoudom O. J. , Ukaonu C. , Egbele E. , Onyekonwu M. O. 
Published: December 2007

Abstracts
Poor reservoir characterization poses unique problems for exploration and production when the complex variation in lithology and diagenetic history that result in heterogeneous reservoir quality are not addressed. Optimizing field development requires a level of reservoir description that adequately defines vertical and lateral variations in reservoir quality.
An accurate reservoir description is a key to improved field development planning and management. This study shows how integrating petrophysics and geology helps in reservoir characterization.
This is illustrated with data from Niger Delta reservoir sandstone.
Water Coning Diagnosis using Spectral Analysis
Authors: Egbe ThankGod , Appah Dulu 
Published: December 2007

Abstract
Previous attempts at diagnosing the problem of water production in oil wells have been carried out without regard to the random and periodic nature of the problem. By treating the water-oil-ratio(WOR) as a stationary stochastic time series, a new model for diagnosing water production in oil wells based on Spectral Analysis/Fourier Transformation of the random production data is presented.
Key parameters used in the diagnosis and characterization are the autocovariance function, the autocorrelation function and the spectral density function. These functions are respectively used to obtain information about the spectral bandwidth, the correlation structure and energy distribution within each mechanism of water production
This method has been used to produce spectra for the diagnosis of coning using field data. Results show that coning can be modeled fairly closely as a low order autoregressive process with narrow spectrum. The position of the peak power in the spectrum and the periodicity of the autocovariance plot were used to uniquely characterize a typical coning process.
Intelligent Sand Management
Authors: Babs Oyeneyin M. , Macleod Chris , Oluyemi Gbenga , Onukwu Anthony 
Published: December 2007

ABSTRACT
More than 70% of oil/gas reservoirs worldwide are in various degrees of unconsolidation requiring some elements of sand management. This is more so especially in the Niger Delta as activities extend to the more challenging deepwater environments of offshore West Africa.
Debate on the most effective sand management strategy has been intense for many years, with different companies adopting different strategies.
Development of appropriate strategy for the management of reservoirs with sanding problems is rather complex and requires an integrated approach to finding the optimum solution to solving the problem. This requires integration of key aspects of reservoir characterisation, drilling, completion and production technologies including sand tolerances (Seabed wellhead/flowlines, topside facilities) . Mitigation of sanding requires reliable sanding prediction, precise well design, accurate technology selection as well as optimum completion strategy. These are transient phenomena requiring a life cycle real time management.
In this paper attempts have been made to address the key issues with sand management. The paper goes further to provide a case for lifecycle intelligent sand management including the current technological innovations and future challenges in terms of technology gaps
Highlights of some of the development activities ongoing at The Robert Gordon University are also presented
The paper ends with an introduction of the Sand Management Network – A Network of upstream oil and gas operating companies and service providers with interest in sand management. The Network purpose is to share successful methods and technologies as well as promote best practices in the management of sand.
Drag Reducing Agent Test Result for ChevronTexaco, Eastern Operations, Nigeria
Authors: Ibrahim John U. , Braimoh Lucky A. 
Published: December 2007

Abstract
The result of a field test of ConocoPhillips Specialty Products Inc.'s (CSPI) LiquidPowertm Flow Improver, a type of Drag Reducing Agent (DRA), at ChevronTexaco's Inda platform in Nigeria is reported in this paper.
Analytically, Inda platform started experiencing deviation in pipeline pressure drop between the actual and theoretical values in about April 1998 and gradually worsened ( Figure 4 ). However, the impact was not felt as the field was under production curtailment. But in March 2003 when the need to increase production arose, it was discovered that the throughput could not be increased beyond 18,400 bopd. Consequently, various analyses and trouble shootings were carried out. Some of the results point to, reduction in the internal diameter of the pipeline, pipeline frictional losses, repair works needed on pumps amongst other problems. And subsequently, the search to finding a technology that would enable the production of additional 2500 bopd shut-in as a result of this pumping handicap commenced. Several companies’ drag reducing agents were evaluated and ConocoPhillips’ LiquidPowertm Flow improver was selected for field test.
Upon selection, the LiquidPowertm Flow improver was imported and tested on the Inda PP. The primary test lasted for about 36 hours and was followed by a prolonged secondary test. Some of the challenges faced were mobilizing the hard and soft wares for the test since all the equipment were been imported from Europe (CSPI office base). Also because the Inda crude is injected to a third party facility, we had to contend with seeking approval of the third party company. Additionally since this is the first time the product is being tested in ChevronTexaco Nigeria, we had to contend with pioneer status challenges like extensive discussions, buy-in difficulties, money sourcing, logistics, etc.
At the end of the testing period, discussion and analysis were made on what should be the way forward for the extensive use of the DRA and thereafter business decisions were made.
Critical Success Factors for Well Stimulation
Authors: Nnanna Erasmus J. , Ajienka Joseph A. 
Published: December 2007

ABSTRACT
The popularity of matrix stimulation as production enhancement operation is evidenced by the abundance of technical resources on the subject matter. Developments in technology have continued to address the challenges of the operation.
This paper identified three critical success for well stimulation as good candidate selection, well-engineered treatment design and improved field operations. The approach was simple and involved a review of existing case histories with a view to identifying issues that need closer attention for the optimization of matrix treatments.
The use of the R-Factor for candidate selection was revisited and an expression that excluded BHP data and rock and fluid properties was derived to ease the calculation of this factor.
An attempt was also made towards the design of the treatment volume of the acid based on the completion details of the well. Charts were presented for this. Field cases that illustrate the importance of this new approach were also presented.