bluuebunny/crossref_metadata_2025_split huggingface dataset:
Technical, Economic & Legal Considerations for Successful Projects in the Oil Industry
Authors: Cedeno I. , Moreno M. S. , Polit E. 
Published: November 2015

Abstract
This paper proposes a multidimensional approach for the integration of technical, economic and legal & contractual components and the interrelation of the parties involved in the development of Upstream & Downstream projects in the oil industry –and not on an individual, separate, or partial basis– in order to efficiently and effectively achieve the success of the project through the optimal usage of investments and resources while minimizing risks which may result in losses for the parties or the failure to reach jointly the mutually agreed goal.
Based on projects developed in Ecuador in the oil industry which outcome was a success and/or a failure, we will identify through the variables which contributed to said success and/or failure and the interrelation among them. The success and/or failure is not a lineal function of the variables, as these individually do not lead to the outcome but it is their synergy which unfolds the results.
This method has only been applied on a retrospective basis, that is, after the fact, in order to revise actions and steps taken to determine the reasons for failure. The application of the multidimensional approach have enabled us to reach the conclusion that in certain projects results could have been different. It will only be useful if new future projects are analyzed a priori and results evidence positive consistency.
Without foundations, it has been thought that the oil industry as an extractive industry is only a basic industry which does not vary or incorporate and/or require methodologies to effectively and efficiently optimize the execution of projects. To the contrary, this industry has led the way for the development of other industries. Based on the universal nature of the oil industry, we may incorporate an educated analysis that will be pioneer for other industries.
Frequently it has been observed that there is a divorce among the technical, economic and legal professionals managing an oil industry project unaware that joint efforts will provide synergy to the analysis, in order for the final result to be more effective and efficient than those results originated from individual efforts. This Paper incorporates a multidimensional analysis for the development of projects in the oil industry.
Strategy Model for Petroleum Contracts: A Holistic Sensitivity Analysis of Oil Royalties to Hydrocarbons Commercialization.
Authors: Bravo Reynaldo Cervantes , Huerta Víctor Alexei , Chun Néstor Palacios 
Published: November 2015

Abstract
The development of a petroleum exploitation strategy is essential for any country for developing its petroleum resources. Petroleum exploitation strategy includes a series of policies relating to licensing, taxation, royalty, and legal instruments. Contractual agreements are developed by the state in order to ensure the orderly development of petroleum exploration and production. In the absence of a clear petroleum exploitation strategy, the international oil companies of Peru and Latin American would not be able to assess the political and economic risks to the preservation of the reserves in a focus of commercialization.
The proposed methodology comes from a study of the forecast of WTI oil price in its inference (0.650%) annual, (0.645%) monthly as in its daily. It is subject to progressive decreasing jumps every five years at 50% for the factor of the prospective increase (PI), caused by external agents (Positive turning: 30.48%; Negative Turning: – 36.04%), then evaluate the 3 scenarios (Proved Developed Reserves,1P and 2P) with case studies for WTI: Low, Base and High.
The sustainability of the Reserves status is initially defined from a deterministic approach, and followed by the development of a programming language for the interpretation of the simulation of royalties under a probabilistic approach in the contractual period.
Since the International Oil Companies are major sources of the intensive capital, and sophisticated technologies needed for exploration and development of petroleum resources, it is essential for a country to formulate a coherent and well-balanced petroleum exploitation contractual strategy. This should be consistent with its social and economic goals and at the same time allow the international oil companies to generate economic profits that in some way relate to the level of risk involved in obtaining these profits and setting a rate of minimum refund of 100% since 2020 year.
For 2026, it seeks to have an incentive by the State regarding the minimum royalties for oil light (35%), and raw Median-Heavy (25%) independent of WTI oil price variability in the probable and possible reserves in addition to the incorporation of Integral rate of refund. Likewise, there is a tolerance of up to 25% in the return on investment for the company to verify an additional investment in the development of resources within the last 10 years of the oil contract.
Based on the Forecast WTI and stage of development (1P) simulation explains a range of royalties between (35-40) % for light crude and, (25-27) % for Medium-Heavy crude; under the conditions of investment recovery of 50%.
Integrated Applications of Fiber-Optic Distributed Acoustic and Temperature Sensing
Authors: Hveding Frode , Porturas Francisco 
Published: November 2015

Abstract
Distributed Acoustic Sensing (DAS) and Distributed Temperature Sensing (DTS) measurements are leading edge technologies which are adding great benefits and solutions to a series of well and reservoir monitoring surveillance and management challenges. The main goal is to optimize the reservoir performance to achieve higher ultimate recovery, higher production, monitor overburden geomechanics, acquire wellbore seismic data, and monitor well integrity at a lower cost in both conventional and non- conventional reservoirs.
DAS in combination with DTS offer qualitative and quantitative data for understanding the fluid dynamics both near and far from the wellbore to aid in decision making for optimal reservoir management. This is where fiber-optic DTS and DAS technology either permanently installed or temporarily deployed in the well can provide information on-demand at a low cost and minimal risk of failure.
Enhanced reservoir management employs multiple integrated technologies for optimal area sweep, drainage, and recovery, as well as increasing the productivity index or injection conformance at the well, group and or field levels. Composite carbon rod deployed fiber-optic Distributed Temperature Sensing (DTS) and Distributed Acoustic Sensing (DAS) systems are one of the innovative technologies that has become available for real-time monitoring in support of advanced intervention methods and enhanced reservoir management.
In non-conventional reservoirs fiber-optic are useful for monitoring hydraulic fracturing operations, and flow profiling during production. DAS and DTS measurements add a new dimension to gain knowledge from each perforation stage in long horizontal wells to optimize completions design and increase production efficiency and well performance.
This paper presents a detailed description of the main steps followed to deliver timely and valuable DTS/DAS solutions and shows results from key field applications.
Commingled Reinjection of Cuttings and Produced Water Provides a Zero-Discharge Solution for the Development Phase of the Pirana Field in the Peruvian Amazon Region
Authors: Poclin H. R. , Watanabe J. F. , Ortiz H. 
Published: November 2015

Abstract
Drilling and production operations in sensitive areas require an effective and efficient waste management plan to minimize the impact on the environment, especially when environmental legislations are strict. Waste management is a decisive factor during oilfield planning operations from an environmental and economic perspective. Often, the waste management method used depends on the type of operation (exploratory drilling, development drilling or production) and the environmental regulations. The waste related to drilling operations can include solid waste such as drilling cuttings and chemical products used for drilling fluid preparation, and liquid waste such as drilling fluid, contaminated rainwater and rig washes. Production waste comprises (mainly) completion fluids, produced water and oil-contaminated fluids. Cutting re-injection (CRI) technology is an accepted method for disposal of drilling cuttings and drilling-associated liquids. Produced water is usually injected into a subsurface formation for final disposal or to maintain reservoir pressure during production.
According to conventional oilfield practices, both disposal options occur separately in different wells. Currently, commingled injection of both drilling cuttings and produced water in a same well is an interesting option if it is properly addressed.
The article presents the commingled re-injection of cuttings and produced water during the development stage of the Pirana field as a cost-effective and environmentally friendly waste management method. The development of the Pirana field began in 2013 with seven producer wells and one injector well. During the 2013 campaign, the injector well was dedicated to only the re-injection of cuttings. After production started (at the end of 2013), the well was dedicated to only produced water injection until the beginning of the second drilling campaign (in 2014), where five additional wells were drilled and commingled injection began in the same injector well. Produced water was injected with periodic injections of drilling waste.
Implementing Long Stroke Reciprocating Rod Lift in Re-Entry Wells
Authors: Villacis Nelly , Solá Ana , Alvarez Fabián 
Published: November 2015

Abstract
This paper describes the results of implementing a Long Stroke Pumping Unit (LSPU) on a re-entry well at Auca field, Ecuador which is operated by the National Oil Company (NOC) Petroamazonas EP.
The optimization of the artificial list system on the selected well, was recommended after careful examination of several parameters such as: mechanical constraints due to well geometry, high depth and high degrees of deviation, low rate of production, low API gravity that in conjunction caused the existing hydraulic jet pump completion to operate at lower efficiency rates.
A few of the benefits of proposing an optimization on the lifting method are: The use of a LSPU with its 288 in stroke length allows for fewer reversals and thus less cycles in the downhole equipment allowing for a longer run life when compared to other pumping units.Tubing-sucker rods lateral loads will be evenly distributed with an appropriate guiding program.Specialty Downhole equipment such as an insert pump anchor, and a two-stage hollow rod pump allows the operator to save in intervention times up to 40% in costs since does not require use of workover, but only a flushby truck unit
In addition energy consumption is reduced without affecting the rate of production of the well, thus with all these considerations reciprocating rod lift with a long stroke pumping unit was selected.
Unconventional Completion Design for Deep Geothermal Wells
Authors: Okech Roy Radido , Liu Xiaolei , Falcone Gioia , Teodoriu Catalin 
Published: November 2015

Abstract
Harnessing geothermal energy faces many of the challenges encountered in the exploration and production of oil and gas. Deep drilling is a necessity to attain sufficiently high temperatures for successful recovery of unconventional geothermal energy, such as in Enhanced (or Engineered) Geothermal Systems (EGS). The challenge of deep geothermal exploitation is comparable to that posed by high-pressure, high- temperature oil and gas projects. Accessing such deep targets, and the need for suitable well completions, means operators incur increased capital and operational costs.
To date, the implementation of EGS, following the original Hot Dry Rocks (HDR) model, has been dogged by technical problems, lower-than-expected performance and poor public image, as they typically require the "engineering" of the reservoir by artificial stimulation in order to create the necessary heat exchange in the subsurface.
Here, conventional and unconventional deep geothermal development well concepts are reviewed, breaking down the technologies into three categories: doublets, single well (open loop) solutions and single well (closed loop) heat exchangers.
This paper then focuses on the original Borehole Heat Exchanger (BHE) concept for shallow applications, and - based on recent experience with medium-depth BHEs for direct use/district heating - discusses variations proposed in the public domain for deep geothermal systems, with the ultimate goal of generating electricity under current economic conditions.
A New Reservoir Classification Based on Pore Types Improves Characterization - PART B
Authors: Jonathan Soto O. , David Soto O. , Rodolfo Soto B. 
Published: November 2015

Abstract
This is the second of a two-part article of a new reservoir classification based of pore types. We discussed in the first article a new methodology developed in order to classify all kinds of reservoirs worldwide: fracture, matrix, vugs, or combinations of these using the cementation factor, mvariable, and fuzzy logic concepts. The new classification presented was based on a 2D Model and we identified at least five types of reservoirs according to pore types. This article provides the updated reservoir classification using a ternary diagram based on fractures, vugs and/or intercristaline pore systems. We show in this paper how to use core, log, field data and fuzzy logic to build a confident petrophysical model, for complex reservoirs; and how to determine which kind of reservoir belongs to the new classification; and discuss the best practices of how to exploit and increase hydrocarbon production and reduce the uncertainty of the original oil in place calculation.
Key Parameters to Revitalize Mature Oil & Gas Fields
Authors: Quiñones V. A. , Bravo R. J. , Chun N. Palacios 
Published: November 2015

Abstract
Nowadays, exploration efforts are becoming harder taking into account that worldwide new hydrocarbons have been discovered in frontier areas such as deep water fields and artic oil, as well as, remote, almost inaccessible and environmentally sensitive places, such as oil and gas fields in the Ecuadorian and Peruvian jungle. Monetizing hydrocarbons in such sensitive places require time and addressing technology, logistics, commercial and environmental-social issues.
Many companies and governments have shifted his strategies to look "new oil" in mature fields either by redefining development strategies or by applying enhanced recovery technology. Based on experience and application in many oilfields in the region, some key parameters were identified as critical to bring new life to brown fields.
Based on worldwide experience, three (03) key parameters are considered critical to incentive and promote "re-development strategies" in brown fields in Peru for new bidding processes ratio of proved reserves replacement, royalty taxes based on financial performance (ratio between NPV and CAPEX) and an "incremental profit" for secondary and tertiary oil.
The purpose of defining a 100% ratio of proved reserves replacement is to set a threshold production curve for bidders that will assure an extended production life of the hydrocarbon asset even after finalizing the new contract period. The ratio of proved reserves replacement is focused on fostering short-term strategies such as production optimization, reactivation of wells and infill drilling; since this key indicator is focused on increasing progressively proved reserves as companies redeveloped the fields, they will be comfortable to deploy investments under "low risk scenarios" to increase recovery factor in mature fields. In addition, the application of the proved reserves replacement ratio in new bidding processes will help state to address long-life reserves to production ratio and sustainability of country's energy supply.
On the other hand, the definition of a tax royalty based on financial performance will address a window range of multiple simultaneous scenarios in which the profits of government and companies concur to equitable financial performance of 50%. This provides a more reasonable timeline for companies to deploy investment and help the state and contractors to arrive to a fair distribution of oil rents.
The incorporation of special tax regimes and rates, as well as, a preferential royalty in new oil contracts will push companies to look new ways to apply technology in mature fields (multilateral wells, modern completion systems and enhanced recovery processes) so as to probable and possible reserves, as well as, contingent resources might be converted into proved reserves. The index of Proved Reserves Evolution and the Ratio of Proved Reserves Replacement would be useful to account for these movements.
Understanding Controlled Salinity Waterflooding in Carbonates Using Streaming Potential Measurements
Authors: Al Mahrouqi D. A. , Vinogradov J. , Jackson M. D. 
Published: November 2015

Abstract
Modifying the composition of injection brine can cause wettability alteration and lead to enhanced oil recovery (EOR) from carbonate reservoirs. The two main approaches are: (1) dilution of injected brine and (2) selective modification of the concentration of potential determining ions (PDIs) such as Ca2+, Mg2+ and SO42-. Each of these approaches will modify the surface charge of carbonate mineral expressed in terms of the zeta potential. Here we reports measurements of the zeta potential of intact carbonate samples obtained using the streaming potential method. This method allows us to directly link zeta potential and oil recovery in the same coreflooding experiments. We begin by using single-phase (brine only) experiments to investigate the effect on zeta potential of dilution and PDI modification using seawater as a reference injection brine composition. We then use multi-phase experiments (brine displacing oil) and carbonate samples at different initial wetting states to determine the correlation between injection brine composition, zeta potential, EOR and initial wetting state, using the same brine compositions as in the single-phase experiments. We find that typical formation brine yields a positive zeta potential, whilst seawater yields a negative zeta potential. Consequently, injection of seawater leads to a change in the polarity of the zeta potential and therefore affects fluid-rock interactions. This in turn affects oil recovery. Dilution of injected seawater and an increase in SO42- concentration both yield a more negative zeta potential compared to the seawater reference case. However, the change in zeta potential observed when adding SO42- is less than for bulk dilution. The magnitude of the zeta potential increases in the presence of an oil phase after aging and similar increase was observed on diluting the injection brine. In the experiments reported here, incremental oil production was not observed. We suggest that the increase in the zeta potential, and consequent increase in the electrostatic repulsion between the similarly charged mineral-brine and oil-brine interfaces, explains why most of the oil is produced during first brine injection. Other samples, which were not aged, yield no change in zeta potential compared to water-wet cases within experimental error.
Geosteering Operations Using Spectral and Azimuthal Information in the Eastern Llanos Basin- Colombia
Authors: Ballesteros J. , Bravo G. , Cerchiaro J. , Perez M. , Rincon C. 
Published: November 2015

Abstract
This paper highlights the results obtained during the drilling a horizontal well using azimuthal/spectral information to geosteer the well at the top of the reservoir. It also documents the structural/stratigraphic changes along the navigated section by analyzing the reaction of the radioactive isotopes in the overlying and underlying clays of the reservoir.
Abrasive Perforation Technique Optimize Production and Avoid Reservoir Damage in COCA Field Ecuador
Authors: Carrera L. , Morales O. , Sierra F. , Teran N. , Monge A. , Alvarez J. 
Published: November 2015

Abstract
There are several techniques to optimize production and avoid reservoir damage caused in the different phases of the development of oil wells (perforation, completion, production and workover), ranging from the control of water, chemical stimulation, mechanical stimulation, fracture, re-perforation of producing areas, etc.
In the case of phase completion, holes are perforated through canyons to connect the reservoir with the wellbore and get well production, however this technique, often not doing its job, because it does not exceed the damaged area, produced in the drilling phase, when applying sludge systems or the primary cementing is performed, brings further cause damage to the compacted in the vicinity of each hole area.
Abrasive perforation technique was used in 1958 approximately and thanks technological advances in the field of materials and chemistry, has had substantial improvements, has created new expectations for avoid formation damage and hence an improvement in the production of oil producing wells.
In order to analyze and predict the well Productivity, it is necessary to perform an appropriate perforating analysis; this can be achieved integrating Petrophysics, Geomechanics, Reservoir and Production Domains. For an advanced Perforating design a clear understanding of rock characteristic, depth of damaged zone and reservoir behavior is used in the Perforating simulation. This enhances the right selection of charges and ensures they will overpass the altered zone.
Abrasive perforation technique has been used to optimize production from oil wells and avoid the reservoir damage to the drilling and completion phase, replacing conventional techniques shooting. This methodology was implemented in Coca Field. This helped to optimize and predict the productivity of the wells.
Acoustic and Microresistivity Borehole Image Logs and Core Data Integration in Well DN-22, Drago Field, Oriente Basin, Ecuador
Authors: Badillo V. , Pérez J. A. , Rengel R. E. 
Published: November 2015

Abstract
Studies of petroleum reservoirs are based on a multidisciplinary integration focused on developing 3D models that honor reservoir heterogeneities; the sedimentological and stratigraphic models play the most important role to honor these heterogeneities; in order to obtain good models it is important to acquire and integrate the highest volume of well data, preferably state of the art technology. This paper presents how electrical log-core data integration obtained a correlation between lithology, lithological accessories, sedimentary structures, structural features, fossils, ichnofossils and fluid impregnation, among others, from the interpretation of two hundred and twenty nine feet of a sedimentary sequence within core data and a high-resolution acoustic-resistivity image log from well DN-22 in Drago field. High-resolution borehole image logs are much more cost effective as compared to coring and subsequent analysis.
From the analysis of the features associated with rock factory (grain size, sorting, roundness) and other associated features like sedimentary and post-sedimentary processes (lithological accessories, fossils traces, diagenetic features), sedimentary facies were identified, which were correlated and adapted to existing sedimentary facies catalog and used for Drago field. Likewise, based on patterns and characteristic responses seen in resistivity and acoustic image log (coloring and shading contrast, texture, clasts, clay laminations, fossils traces, fossils), electrofacies were identified and framed into the same facies catalog. The resulting analysis established eight sedimentary-electrofacies, this contributes to further extrapolate detail sedimentological analysis for coming wells in this field by using high-resolution image logs. This study is unique in the area and will help to better characterize rock properties for field development.