bluuebunny/crossref_metadata_2025_split huggingface dataset:
First Production Results from Pimienta Oil Source Rock Reservoir, a Promising Shale: Case History from Burgos Basin, Mexico
Authors: Araujo O. , Garza D. , Garcia D. , Ortiz J. Ramon , Bailon L. , Valenzuela A. 
Published: June 2014

Abstract
Currently, three unconventional wells have been drilled and three are nearing completion that have been targeted in the Upper Jurassic Pimienta. This source rock formation is a candidate to be Mexico's first shale and could become the most productive shale zone in the country. There are several reasons for this success, which are discussed in this paper.
The primary subject well discussed was targeted in the oil window. Several horizontal completion techniques can be applied when stimulating these wells in northern Mexico; the plug and perforate (plug-and-perf) method is most commonly used at this time. During initial planning, this well was also going to use the plug-and-perf with conventional perforating and stages isolated using pump-down wireline plugs.
However, the particular well discussed here was instead completed by fracturing all the different stages using coiled tubing (CT)hydrajet perforating using a 2-in outside diameter (OD) string. This process employs jet dynamics principles and anew jetting tool design, creating clean, non-damaged perforation tunnels that help reduce fracture initiation pressure compared to conventional perforating. This process creates the most effective wellbore-to-reservoir connection possible, and then creates zonal isolation between stages using sand plugs.
After flowback, this well is considered the best shale producer in northern Mexico with gas and light oil production and has created new opportunities for drilling targeting the Upper Jurassic Pimienta shale, particularly in the oil window in the Burgos basin.
This is the first oil source rock reservoir horizontal well ever completed through the entire lateral section in conjunction with CT in Mexico.
New Drilling Campaign and New Technologies after 10 Years Without Drilling improve Performance in La Ceiba field
Authors: Tinoco Jose , Celis Criss , Lopez Luis , Rodriguez Ernesto , Coronel Gustavo , Lopez Jose , Bits Smith 
Published: June 2014

Abstract
The history of La Ceiba field began 10 years ago when six exploration wells were drilled to assess the potential of this field. The wells were drilled with several incidents of stuck pipe and the resulting necessary side-tracks to reach the final depth. Until last year no further attempt had been made to drill in this field.
With little information available from the exploration wells concerning drilling practices, the drilling campaign began with the goal of improving the previous performance, making the drilling of the complete wells faster and safer than in the previous drilling.
An engineering process was begun to find the best drilling solution for the field, starting with proven technologies such as positive displacement motors (PDM) and drill bits used in similar fields; however, this methods alone were not sufficient to meet the challenges of the field.
New technologies were used for the different challenges and applications through coordinated work between the drilling engineering departments of the different parties involved in this field and using all the information available in the drill bit selection database, including logs and stability data for the tools selected to drill each phase of the wells.
With evolution of the learning curve, drilling progressed from initial drilling involving 12 runs with time-consuming trips to surface to change either the drill bit or PDM, to drilling the same interval in 5 runs with the time on bottom increasing compare to previous experiences due to the introduction of tools more suitable to the environment requirements a rotary steerable systems (RSS) in combination with a specially designed drill bit.
Problems commonly faced in the upper sections were, the trajectory was not strictly followed, were solved with the introduction of the RSS in this section; use of the tool saved 10 days of rig time and set a bench mark for the field and similar wells in western Venezuela.
The development of this field shows that by solving the issues related to the well depth, temperature and constraints well design for these wells in western Venezuela, it will be possible to reach the oil reserves, at the same time decreasing the time spent in the drilling process.
Integrated Analysis To Identify and Prevent Formation Damage Caused by Completion Brines: A Colombian Field Application
Authors: Jaimes M. G. , Castillo R. D. , Villar A. , Escobar M. A. , Dorado R. , Acevedo N. P. 
Published: June 2014

Abstract
After workover jobs, many oil-producing wells have reduced their production, which is caused by formation damage created by using inadequate completion brine. The damage mechanism may be: 1) Block in the face of the formation, produced by the tendency to form emulsions between the oil of the well and the completion brine, 2) Production of inorganic scale in the porous medium during the contact of the formation water with the completion brine, 3) blockage by suspended solids present in the completion brines, 4) Increased bacterial activity in the wellbore vicinity, 5) rock-fluid incompatibility due to sensitivity of the formation minerals to the completion brine, caused by high ion exchange, causing swelling of clays and reduction of the permeability, 6) increase of the water relative permeability.
Given the above, this paper focuses on integrated analysis for selecting appropriate completion brines, based on an analysis of laboratory and production. Laboratory analysis includes: 1) Evaluation of fluid-fluid interactions, 2) physical- chemical analysis of produced water, 3) definition of Scale tendency of produced water and the mixture with control brine at the wellhead and at reservoir conditions through a simulation software, 4) filtration of the base fluid of the control brine and analysis SEM of solid waste found, 5) microbiological analysis of the base water of the completion brine, 6) compatibility brine-rock through test of core -flooding, 7) determination of critical salinity, The production analysis includes a diagnostic diagram with an assessment of the production history, fluid levels, events, extraction conditions, etc.
The integrated analysis was applied in 12 wells in the fields A, and G in Colombia, to determine the root cause of production losses, after workover. The Economic evaluation showed loss of productivity, quantified in more than one million dollars per well.
This paper presents the results of the evaluation in the wells G-11 and A-21, along with the conclusions and recommendations.
Physicochemical Evaluation of Formation Fluids and Stimulation Effluents In Situ: A Way To Ensure the Success of the Jobs
Authors: Jaimes M. G. , Villar A. , Escobar M. A. , Prada T. A. 
Published: June 2014

Abstract
The assurance and optimization of stimulation jobs has become very important due to the need to increase profitability in the crude oil production and ensure, as far as possible, the success of operations.
The chemical stimulation jobs consist in removal of formation damage and, in this regard, different types of fluids are designed in order to act on specific types of damage. However some oil wells commonly have several types of damage at the same time so, in the design phase it must be assured that each phase of the stimulation is carried out without interfering with the others. Otherwise there can be a number of undesirable consequences product of incompatibilities between stimulation fluids and reservoir fluids. Effluent characterization "in situ", during the stimulation jobs contain valuable information for directing the operation steps in order to prevent interaction of incompatible fluids and ensure the beginning and end of each treatment stage.
This article contains the results of chemical stimulation carried out in the well Sucumbios-5, where physicochemical evaluation of formation fluids and the effluents of stimulation treatments allowed a proper diagnosis on the development of each of the series of stimulation treatments evaluated.
Finally, the main findings and conclusions of the this study are shown.
Economic Evaluation of Steam and Solvent Injection for Heavy-Oil Recovery
Authors: Galvão E. R. , Rodrigues M. A. , Dutra T. V. , da Mata W. 
Published: June 2014

Abstract
In the last years, an alternative more and more used by the oil industry to increase the efficiency of Steamflooding has been the addition of solvents. In this work, a numerical study was done to analyze the influence of some operational parameters (steam injection rate, injected solvent volume and solvent type) on oil recovery. Simulations were performed in STARS, a CMG program. Using Contour Plots, it was possible to analyze the interactions between the operational parameters and to obtain the "optimum" regions for work. Comparisons between the models also were performed using several plots, such as fraction of oil recovered versus production time and fraction of oil recovered versus pore volume injected (PVI). To try to reduce the solvent volume required, were studied some cases of solvent injection interruption. To calculate the Net Present Value (NPV), were considered the sale price of the oil produced, the steam generation cost, the oil production cost and the purchase price of the solvents.
The applicability of the method was investigated in a heavy oil reservoir with properties similar to those found in Brazilian Potiguar Basin (200 m depth, porosity of 30%, vertical/horizontal permeabilities ratio of 10% and thickness around 35 m).
It was found that the solvents addition to the injected steam not only anticipated the arrival of the heated oil bank to the producer well, but also increased the oil recovery. Lower cold water equivalent volumes were required to achieve the same oil recoveries of the models that injected only steam. Furthermore, much of the injected solvent was produced with the oil from the reservoir, what contributed to the method economic viability in terms of NPV.
A significant fraction of the hydrocarbon reserves in the world is formed by heavy oils. The high initial productions achieved by models that use solvents have generally a significant impact on the operation economics. On environmental point of view, solvent injection can provide a reduction of energy and also a reduction in water consumptions for steam generation, having diminished Green House Gases emissions.
Static 3D Modeling at Boscàn Field: Overview of Data Integration and Model Construction Techniques
Authors: Shannon C. , Radecker K. , Waite M. W. , Munoz J. , Leon O. , Valera N. , Paz R. , Perez G. , Pina A. 
Published: June 2014

Abstract
A 12-million cell (150m × 150m × 1m), 3D geocellular model covering the Boscán field has been constructed. This presentation describes the results of this full-field reservoir model construction that has integrated core, well, seismic, pressure, and performance data.
In 2007, new 3D seismic was acquired over the south area of the field. The seismic was reprocessed with pre-existing 3D to enhance mapping of structural and stratigraphic features and provide better spatial control, improving on previous interpretations made with only well data and 2D seismic lines.
The re-processed 3D was used to re-evaluate horizon and fault mapping over the field. Using coherence-based methods, a study of regional tectonics for the area, and well correlation and performance data, we imaged a structural volume and different fault patterns originating from the main field-bounding Boscán fault. Though many of the faults do not have significant vertical offset, they appear to have pronounced effect on fluid movement and compartmentalization.
Electrofacies modeling tying core to logs was used to define trends and spatial probability of reservoir and rock properties across the field. In addition, seismic attribute data was qualitatively used to help guide reservoir variability between wells and define potential depositional features within a tidally-influenced fluvial-deltaic system.
Multi-point statistics (MPS) was applied to allow use of field-scale regional trends and shapes that mimic depositional features to ensure that spatial probability derived from seismic and well data could be honored. Multiple scenarios have been generated that capture the uncertainties in reservoir connectivity and associated distribution of rock quality parameters across the model area. Cells were populated with two-component lithofacies, volume of shale (VSH), effective porosity (PHIE), effective water saturation (SWE), and permeability (PERM) using a Petrophysical model developed from an extensive database of 1000+ wells.
The full field 3D geocellular model has been downscaled to several workable smaller sector models to help address specific past performance and future dynamic behavior. Production history matching and numerical fluid flow simulation is currently underway. The focus of the history matches, in part, is to shed light on fault compartmentalization, reservoir connectivity and quality distribution, and fluid movement associated with an encroaching aquifer and water injection for pressure maintenance through time.
Conceptual Study and Experimental Protocol for the Selection and Evaluation of Matrix Stimulation Treatments with Biocides, Focused on H2S and Corrosion Control in Producer Wells of Fields Undergoing Secondary Recovery
Authors: Jaimes M. G. , Villar A. , Escobar M. A. , Acevedo N. P. 
Published: June 2014

Abstract
One of the major problems in mature fields undergoing secondary recovery is the contamination with sulfate reducing bacterias (SRB) of the injection water system (fresh and/or production) and/or of the reservoir (natural or by drilling fluids, completion, stimulation, etc.), which causes formation damage and microbiological induced corrosion (MIC) in the injection-production system.
The problems mentioned above are present in various fields of the state oil company, Ecopetrol S.A, in Colombia and the situation is becoming more critical, not only because the decrease in productivity (formation damage, failure of the subsurface equipment and facilities of the Injection-Production system, etc.), but mainly because the risk of human mortalities (maintenance jobs, nearby houses, etc.).
In some producing wells, H2S concentrations have exceeded the lethal limits of 20 ppm and there are cases of producing wells with levels above 1000 ppm. Based on the above, a conceptual study was developed and an experimental protocol for the selection and evaluation of matrix stimulation treatments with biocides, focused on H2S and corrosion control in Producer Wells of Fields Undergoing Secondary Recovery as part of the comprehensive strategy to implement in the injection-reservoir-production system of the Cira - Infantas field in Colombia. This study included the following stages: State of the art to define main Bactericides-sporicidal.State of the art to define matrix stimulation treatments to H2S and corrosion control, removal of biomass (biofilm) and iron sulfide, etc. in producers wells.Deactivation of bactericides and sporicides with gases and minerals of the formation (H2S, Clay, etc.) and the environmental Impact.Alternatives Assessment Matrix.Formation damage by growth of sulfate-reducing bacteria.Experimental protocol and results of selection and evaluation of biocides and stimulation treatments.
Finally, the main findings, conclusions and recommendations obtained in this study are shown.
3D Seismic Interpretation Techniques for Detecting Oilfield Exploration Locations
Authors: Carrasco J. , Garcia R. 
Published: June 2014

Abstract
New automated volumetric seismic interpretation techniques have been developed to help reduce cycle times for exploration and reservoir characterization. At the end of the last century, the introduction of seismic interpretation methodologies assisted by computer systems facilitated the development of classical criteria and geological methods for defining the shape of hydrocarbon reservoirs. This latest development allows for the definition of the structural dimensions of the reservoir to be determined without requiring the interpretation of the horizons in seismic sections. This automation of seismic interpretation does not replace the specialist's experience but contributes to the conceptualization of the reservoir structure in less time.
These techniques are designed to determine the volume of the reservoir structure by using seismic geobodies, which define the area and thickness of the reservoir structure. The geobodies are extracted from a window of seismic amplitudes with dynamic ranges using an opacity filter to capture the strongest seismic reflectors, which can be negative or positive, depending on the sedimentary environment. Formation tops from wells are used to correlate the multi-Z components of the geobodies.
The interpretation of the fault system is accomplished by using structural and seismic attributes (including similarity, semblance, maximum curvature, and amplitude volumes) that highlight the lateral differences of the seismic trace properties (amplitude, frequency, and phase). These discontinuities can conform to alignments that reveal fault planes and fracture patterns. The combination of structural seismic attributes with the original seismic cube (no filter and no gain) provides elements that define the main reservoir structural alignments. The interpretation of faults defined by structural patterns is performed without rescaling so as not to lose the three-dimensional (3D) perspective of the fault plane.
Velocity model calibration is important for performing the time-depth conversion of seismic interpretation elements (horizon, fault planes, and seismic volumes). The calculations of the probable seismic attribute hydrocarbon indicators in the petroleum system analysis allow potential areas of hydrocarbon entrapment to be identified by structural and stratigraphic contacts.
This methodology has been successfully applied in a conventional reservoir in Mexico's southern region.
Evaluation of Completion With Method Unconventional Pilot in the Field Motatan
Authors: Barrios J. L , Diaz G. , Rosales L. 
Published: June 2014

Abstract
In the field Motatán 55% of active wells are producing with Gas Lift, 35% occur with BES and the rest with mechanical pumping, but in recent years the compressor plants worked poorly due to the obsolescence of such. The application of conventional mechanical pump is low, because the well is deep and this restricts the settlement of the pump. This has motivated evaluate alternatives leading to a decrease deferred production wells.
This is the case study of the well MOT-67 block located in the largest reserve of crude Motatán area, specifically in western Venezuela. The last three teams Pumping electrosumergible not last more than 3 months since, had binding by the presence of carbonates and asphaltenes, the anomalies were observed in the teardown conducted surface pumps. It is well to note that this brings with BES 920 bbpd system with 32% AyS.
The team integrated of Engineers Reservoir and Optimization analyzed other artificial lift methods that may be feasible for MOT-67 well, including: gas lift and mechanical pumping. During the analysis it was determined to go with the option of gas injection is not have sufficient volume to ensure the reliability of the LAG, in our simulation the well required a minimum consumption of 1.5 MMPCNPD, and conventional mechanical pumping system that could handle generate a maximum load of 50,000 Lbs, this would limit production under this method, due to the setting depth of the pump (9000 feet), and that the unit would work surface to the maximum limit, risking the collapse of the structure, fatigue and wear of the spokes.
Due to the above stated relative to the change in method of artificial lift MOT-67 well, the next question is formulated, Is it possible to combine the Mechanical Pump System with gas lift?
Respective designs were conducted to evaluate the method of mechanical pumping + LAG with special simulators for each production method, proving beneficial.
Effect of Extending the Radial Superposition Function to Other Flow Regimes
Authors: Escobar Freddy Humberto , Alzate Hernan Dario , Moreno-Collazos Leonardo 
Published: June 2014

Abstract
Nowadays, the oil industry is focusing its effort and interest on gas shale reservoirs. Gas shale wells are normally tested by recording the flow rate values under constant pressure conditions. Therefore, time superposition is required in order to conduct transient-rate analysis which normally uses the radial solution of the constant-rate diffusivity equation. This superposition function is also applied indiscriminately to other flow regimes without considering the possibility of an existing error. The literature only reports a case where this situation is dealt with. However, the analysis is performed using curve-decline matching.
This study presents the analysis of the effects generated by extending the superposition time function generated with the constant-rate radial solution of the diffusivity equation to other well-known flow regimes. The work consists of performing simulations for the following scenarios: variable rate under constant well-flowing pressure, uncontrolled changes in flow rate, isochronal uncontrolled changes in flow rate, isochronal increasingly changes in flow rate and isochronal decreasingly changes in flow rate. Superposition time functions were generated for each scenario to compare each flow regime (linear, bilinear, elliptical, spherical and pseudosteady state) superposition function to the radial flow superposition function.
In general terms, it was found that the generated effects of using the radial time superposition function are negligible. Even, good values of the average reservoir pressure with the radial flow superposition function were obtained. However, it was noted a notorious deviation of the linear and bilinear flow regime tendencies for hydraulically-fractured wells. This leads to erroneous estimation of the fracture parameters.