bluuebunny/crossref_metadata_2025_split huggingface dataset:
Changes In Texas Air Emission Grandfathering Rules
Authors: Trout Leonard , Johnstone J. E. 
Published: December 2007

Abstract
The Texas Commission on Environmental Quality (TCEQ) formerly Texas Natural Resource Conservation Commission (TNRCC) is presently implementing new rules to permit Grandfathered facilities in Texas. This will have tremendous impacts for the oil and gas industry. Oil and gas facilities that were once exempted from New Source Review (NSR) under the Grandfathered rules will have to obtain permits and have required control equipment installed in accordance with the new regulations. This paper describes the anticipated rule requirements and discusses the impacts and compliance measures on the oil and gas industry.
Grandfathered facilities are sources of air pollution that were operating prior to the beginning of the Texas New Source Review (NSR) Permitting program. These facilities were exempted from the NSR permitting program. Generally these are facilities that were constructed prior to August 30, 1971.
Exploration and production operators may find that they have many sources of facilities that were "grandfathered." Grandfathered facilities may include compressor engines, gas treating equipment, tanks, flares, vents or other equipment that did not need to be permitted then, but does require a permit now. A good "rule of thumb" when determining if you need a permit is to decide whether, if you were installing that equipment now as a new item, if a permit would be required.
Production of Pipeline Quality Natural Gas with the Molecular Gate® CO2 Removal Process
Authors: Wills James , Shemaria Mark , Mitariten Michael J. 
Published: December 2007

Abstract
In May of 2002, the first Molecular Gate®–Carbon Dioxide Removal system for the removal of carbon dioxide and water was started-up at the Tidelands Oil Production Company operated facility in Long Beach, California. The feed source for the unit is hydrocarbon rich, water-saturated, associated gas from water flood enhanced oil recovery operations. The feed CO2 concentration varies widely and is typically over 30% while the unit reduces the carbon dioxide level to less than 2%. The unit removes the carbon dioxide, heavy hydrocarbons and water producing pipeline specification gas for sale to the local natural gas utility company.
Successful Utilization of Performance Fluids Management in Gulf of Mexico Region 6 Assures Environmental Compliance
Authors: Rojas J. C. , Schonacher D. , Gharst J. , Paiuk B. , Billon B. 
Published: December 2007

Abstract
Meeting the new Gulf of Mexico NPDES environmental regulations (maximum 6.9% oil-on-cuttings), while simultaneously improving drilling performance has been achieved through the implementation of a Performance Fluids Management (PFM) process. This paper describes the creation and application of a fit-for-purpose GOM PFM process, which is a management process that integrates all fluids and waste management-related activities.
This paper will show how the new NPDES (National Pollution Discharge Elimination System) regulation (maximum 6.9% oil on cuttings) was met without impacting drilling operations, while at the same time reducing costs 8 % ($3.5 million) in 2001. Key components of the PFM process include implementation of a common format for fluids management programs; establishing and defining key performance indicators; end-of-well recaps; a weekly PFM report capturing target and stretch performance measures; PFM audit process; skills assessment tools for fluids and PFM engineers; and a model to predict accurate PFM cost/volumes generated.
In order to achieve the objective of reducing the oil-on-cuttings to meet regulatory requirements, the PFM seven-step process was utilized. This process includes expectations, analysis, modeling, setting goals, planning, execution and reviews.
The reduction of oil-on-cuttings (OOC) from 14% to less than 6.9% in the GOM was a very important objective to improve the quality of the discharges to reduce environmental impact. It was very important that drilling performance should be maintained or improved.
The PFM process integrates fluids and waste management. This paper discusses the application of the PFM process.
The authors will present figures showing the following improvements:
Reduction in days per 10,000 ft Reduction in oil-on-cuttings (OOC) Reduction in downhole mud losses Reduction in actual cost compared to AFE Increased mud recovered
The PFM process has been implemented in Colombia, Bolivia, Argentina and Trinidad, where it delivered similar savings.
The process is applicable to wells in excess of $7 million total cost.
Meeting Zero Discharge Requirements in the Gulf of Mexico Using a Unique Cuttings Transport System
Authors: Schonacher D. , Rojas J. C. , Gharst J. , Paiuk B. 
Published: December 2007

Abstract
Zero discharge regulations for non-aqueous drilling fluids used in EPA Region 4 of the Gulf of Mexico have changed the way operators manage drilling fluid and cuttings waste handling and disposal, especially in deepwater. These regulations were considered heavily during the planning stages of two deepwater wells in Desoto Canyon. This paper describes the development and application of the unique cuttings transport and management project that resulted in two successful wells being drilled in EPA Region 4 with no spills, accidents, or negative impact to drilling operations. In addition, when compared to conventional skip-and-ship operations, this system eliminated over 500 crane picks during the course of the two wells. Accordingly, a detailed installation survey was conducted for the assigned drilling vessel
Gas Well Performance at Subcritical Rates
Authors: Sutton Robert P. , Cox Stuart A. , Williams E. Glynn , Stoltz Ronald P. , Gilbert John V. 
Published: December 2007

Abstract
Gas wells producing late in their life are normally subject to liquid loading problems. As rates fall below the critical rate necessary for unloading, a static liquid column will often develop in the well. This can result from condensed water out of the gas phase or formation water being produced into a well having insufficient gas velocity to clear the liquid from the wellbore. The presence of this liquid column impairs the well performance by imparting additional back pressure on the reservoir. The water saturation around the wellbore can increase causing a reduction in the near well effective gas permeability which further compounds the problem of keeping the well unloaded. Traditional methods of evaluating well performance do not properly capture this phenomena; therefore, the existence of additional back pressure on the reservoir can go undetected. Wells continue to produce, but at a reduced rate because of the liquid column. Numerous analysis techniques are available to model static liquid columns in wellbores. A review of these methods and an evaluation of these techniques is presented. Comparisons with field data are made to ascertain the accuracy of the methods and to select an appropriate method to model well performance. Incorporation of this method into a well design allows for the optimization of well productivity.
Design Optimization of a Rotary Gas Separator in ESP Systems
Authors: Harun A. F. , Prado M. G. , Doty D. R. 
Published: December 2007

Abstract
This paper presents the optimization study of a rotary gas separator (RGS) in ESP systems by improving the performance of the inducer part of the RGS. Using two-phase flow inducer model, sensitivity studies were performed to three inducer blade geometrical variables, i.e., tip diameter, pitch length, and total number of pitch, to evaluate the inducer performance in terms of head generation and gas handling capacity.
These studies show that the inducer performance is sensitive to the blade tip diameter and pitch length. Increasing the blade tip diameter and pitch length enlarges the inducer cross sectional area, which in turn increasing the liquid deceleration. This mechanism is responsible for increasing the head generated by the inducer and the sustainability of the inducer in handling free gas. These studies also indicate that increasing the total number of pitch causes detrimental effect to the inducer performance.
These findings suggest that the tip diameter should be made as large as possible within the tolerable size of the pump housing. Similarly, the pitch length should be extended as long as possible within the mechanical integrity tolerance of the whole RGS assembly.
The implementation of the inducer performance sensitivity study results on a typical 400 series RGS indicates that the RGS performance can be improved by enlarging the inducer blade tip diameter and the pitch length. However, the improvement becomes marginal as the gas-liquid ratio increases, which might indicate the limitation of the 400 series RGS application.
Full, Short-, and Long-Time Analytical Solutions for Hindered Matrix-Fracture Transfer Models of Naturally Fractured Petroleum Reservoirs
Authors: Rasmussen Maurice L. , Civan Faruk 
Published: December 2007

Abstract
Previous matrix-fracture transfer models overlooked the hinderence effect of the fracture surface conditions on petroleum recovery from naturally fractured reservoirs. These models are simplistic and do not represent the matrix-fracture transfer with sufficient accuracy.
This paper presents improved matrix-fracture-transfer models and approximate analytical solutions for petroleum recovery from naturally fractured reservoirs. The restricted and hindered matrix-fracture interface fluid transfer phenomenon is considered in order to account for the finite-skin effect of the matrix block surfaces by various processes, including the formation of a stationary fluid film or an actual skin because of formation damage by various processes, such as deposition of minerals and other debris, and adverse rock-fluid interactions. The slab, matchstick, parallelepiped, cylindrical, and spherical type simpler shapes are considered to represent the matrix blocks formed by intersecting fractures in petroleum reservoirs. Then, full scale, and short- and long-time analytical solutions are presented. The analytical solutions are derived also for special boundary conditions involving the rectangular and cylindrical shape rock samples used in typical laboratory tests to represent the matrix blocks. The functional behavior of the transfer functions is demonstrated using various charts and the practical straight-line plotting schemes are presented for effective interpretation of experimental data.
The present model can accurately represent the matrix-fracture interface fluid transfer over the full range of the fluid recovery period, while the previous models can only represent either the early- or the late-time behavior with limited accuracy. The present analytical solutions can be instrumental in developing effective and accurate simulation of oil and gas productions from naturally fractured reservoirs. The new models provide alternative matrix block shapes, skin effect of the matrix block surface, and variable shape factors. Whereas the previous models primarily assumed constant shape factors, ignored the skin effect, and considered a few simple block shapes. The new improved transfer functions are advantageous because these consider variable shape factors and are applicable for primary recovery of gas or oil reservoirs involving single-phase flow and waterflooding or secondary recovery of oil reservoirs involving two-phase flow. The special analytical solutions developed for laboratory core samples can be used for interpretation and evaluation of the results of laboratory core tests.
New Rheological Correlations for Guar Foam Fluids
Authors: Khade Sudhakar D. , Shah Subhash N. 
Published: December 2007

Abstract
Foams provide highly attractive alternative over conventional non-Newtonian fluids for various oil and gas industry applications because of their high viscosity and low liquid content. Foams have long history of proven performance in well stimulations, drilling, acidizing, cleanout operations, and enhanced oil recovery. Foam apparent viscosity is used in hydraulic (pressure drop) calculations for various pumping operations. Thus, accurate rheological characterization is very important to predict viscosity of foam.
In this investigation, rheological experiments are carried out with guar gel and guar foam fluids rheology using a ½-in. pipe viscometer at 1000 psi and temperature ranging from 100 to 200 °F. Guar, surfactant and nitrogen are used as the gelling agent, foaming agent and gas phase respectively. Foam formulations were prepared and tested for qualities ranging from 0 to 80 % at several flow rates.
The present study has shown that both guar gel and guar foam fluids exhibit a behavior analogous to the Power law model fluid. The experimental data are used to develop new rheological correlations to predict Power law fluid flow parameters and thus, apparent viscosity of the foam fluids. These new correlations are functions of temperature, foam quality, shear rate, and fluid concentrations. The correlations were compared with various published correlations. The available correlations in the literature have assumed that the flow behavior index of the foam is similar to that of the liquid phase. This assumption does not support the basic physics that the increase in viscosity decreases flow behavior index. Our results show that the above assumption is not valid and leads to a prediction of extremely low apparent viscosity of foam fluids. In contrast to the previous studies, we report high apparent viscosities of foam fluids at high qualities.
A Successful Methanol Treatment in a Gas-Condensate Reservoir: Field Application
Authors: Al-Anazi Hamoud A. , Walker Jacob G. , Pope Gary A. , Sharma Mukul M. , Hackney David F. 
Published: December 2007

Abstract
A field test was conducted to investigate the effectiveness of methanol as a solvent for removing condensate banks that form when pressure in the near wellbore region falls below the dewpoint. Core flood experiments on Texas Cream Limestone and Berea cores show that condensate accumulation can cause a severe decline in gas relative permeability, especially in the presence of high water saturation. This can result in well productivity declining by a factor of 3 to 5 as bottom hole pressure declines below the dewpoint. PVT analysis performed on field samples taken from the Hatter's Pond field in Alabama indicate retrograde condensate behavior. These high-temperature deep gas wells show low gas productivity and large skin. A preliminary analysis of the data indicated the possibility of condensate and water blocking due to the loss of water-based drilling fluids. Core samples were used to measure gas relative permeability. Compatibility tests were conducted to ensure that the injection of filtrate and methanol did not cause any damage to the core. Since the formation brine is very saline, tests were conducted to check for salt precipitation during methanol injection. Based on these laboratory results and a single-well numerical simulation, a field test was conducted. The well chosen for treatment was producing 250 MSCFPD with 87 BPD of condensate. A thousand barrels of methanol was pumped down the tubing at a rate of 5 to 8 B/min. Gas production increased by a factor of 3 initially and stabilized at about 500 MSCFPD. Condensate production doubled to 157 BPD. The well shows a skin of –1.9 after methanol treatment. The increase in gas and condensate production was observed to persist more than 10 months after the treatment.
Several possible explanations are provided for the positive results obtained in this test. Some general conclusions are made for the design for future treatments.
Laboratory Evaluation of High-Temperature Conformance olymer Systems
Authors: Vasquez Julio , Civan Faruk , Shaw Thomas M. , Dalrymple E. Dwyann , Eoff Larry , Reddy B. R. , Brown David 
Published: December 2007

Abstract
This paper presents the results of laboratory evaluation regarding the effectiveness of novel, organically crosslinked, high-temperature, conformance polymer gel systems as sealants. Effectiveness of these sealant gels is evaluated by attempting water flow through high-permeability cores under residual oil conditions. The effectiveness of the sealants to (1) block water permeability at temperatures up to 350°F, (2) provide long-term sealant properties at these temperatures, and (3)provide adequate gel time for placement is measured. The ultimate goal is to determine whether the selected crosslinked polymer systems provide useable extended gel times and maintain thermal stability to 350°F.
Discussed are (1) the physical laboratory model and test conditions used to perform dynamic core flow studies over extended periods in determining the impact of sealant exposure to elevated temperatures and subsequent required modifications, (2) experimental procedure used for dynamic core flow studies, (3) the effect of temperature on permeability reduction over time, (4) the impact of threshold pressure (differential pressure required before fluid flow begins through a treated core) on permeability reduction over time, (5) laboratory methodology used for gelation time measurement of a new, novel, organically crosslinked, high-temperature, conformance polymer gel system, and (6) laboratory results regarding gelation time of the polymer system as a function of temperature up to 350°F.
Well Performance in a Previously Condemned Prospect: The J Sand Formation in the Northeast Wattenberg Field
Authors: Khachatrian Mikael B. , Trippett Steve W. 
Published: December 2007

Abstract
The J Sand formation is a main pay zone in the extensively developed Wattenberg field of Colorado. Until recently, operators deemed the reservoir in the northeast part of this field uneconomical due to significant production of formation water in this low permeability and sub-pressured gas zone. By modifying the conventional completion techniques of the J Sand, an operator relatively new to the area has been able to economically exploit this reservoir. Key factors that have contributed to the success include improvements in stimulation design and production techniques. Typically, hydraulic fracture stimulation treatments for the J-Sand utilize a low viscosity, guar based, zirconium crosslinked fluid pumped at injection rates up to 24 bbl/min. The above operator differs in stimulation design by incorporating a higher viscosity, low polymer carboxy methyl guar fluid pumped at a relatively low injection rate (e.g. 12 bbl/min). Well performance evaluations utilizing the Reciprocal Productivity Index (RPI) production analysis method in conjunction with log analysis quantify stimulation effectiveness. Treatment pressure history matching with 3D fracture simulators also identify advantages in achieved fracture geometry and proppant placement with the modified treatment design.
Re-Fracturing: Evaluation, Design, and Implementation of a Chester Oil Well in SW Kansas
Authors: Sauer Paul W. , Burns Richard A. , Skees James L. , Aud William W. , Gentry Brooks , Wing Chad 
Published: December 2007

Abstract
This paper will highlight the methodology used to successfully re-stimulate a well that had been unsuccessfully stimulated from previous treatments. A field example will present a well, which was previously treated on two occasions and show the subsequent implementation of a successful treatment that displaced both Ottawa and resin coated sand from the original fracture, enabling the third treatment to be successfully pumped. The initial evaluation methods that were utilized, which included pressure buildup (PBU), reciprocal productive index (RPI), and treatment pressure analyses, will show the damage that can occur when overly aggressive stimulation treatments are applied and present a methodology for evaluating a damaged well. A treatment was specifically designed to remove the proppant pack damage and create an effective stimulation for the character of the reservoir rock. The pressure response from the third treatment will demonstrate removal of the original and the creation of an effective stimulation. Post-treatment production data and analysis is also presented.
Optimization of the Producing Wells (Acidizing-PLT)
Authors: Boussa M. , Bencherif D. 
Published: December 2007

Abstract
Production - Pressure - Skin - PLT - Permeability - Porosity – Acidizing - IP

Summary
The field of Hassi R' mel is a gas condensate reservoir with a superposition of three layers A - B - C having very good petrophysic characteristics and a rather significant oil rim in the Eastern and Southern peripheries.
Producing wells were drilled in the Northern part - Central - Southern with two lines of dry gas injection.
A decrease in production of the wells was observed in the various zones. Build up tests realised on those wells showed significant skin, which is due primarily to the excessive invasion of the mud used during drilling and Work overs.
For that, a study was undertaken in order to see the method to be used for optimisation and to improve the potential of these wells, which is less than that hoped within sight of their petrophysic characteristics.
A stimulation by acidification was decided and 3 companies were selected.
34 wells were realised during this campaign, which was carried out in 3 phases in order to diversify the methods.
1st phase 13 wells; 2nd phase 13 wells; 3rd phase 8 wells.
In order to study the effects of stimulation, PLT's were realised before and after the acidizing.
The purpose of this presentation is to show:
The resulted synthesis of the PLT's carried out on the acidized wells will be analysed and shown in the form of tables and graphs which will enable us to draw a conclusion on the advantages and disadvantages from this stimulation campaign.
Fourteen Years of Progressing Cavity Pumps in a Southern Oklahoma Waterflood
Authors: Oglesby Kenneth D. , Arellano Jose Luis , Scheer Gary 
Published: December 2007

Abstract
The West Hewitt Penn Sand Unit, a waterflood in southern Oklahoma, has utilized progressing cavity pumps (PCP) since September 1988. Producing zone depth is approximately 2100′ with PCP producing rates of 200 to 1100 BPD per well. Through an evolution of PCP configurations and designs a 4+ year pump life can be expected, with only minor repairs. Adjustable rates at the surface, low capital costs, low repair costs and high electrical efficiency are the attractive characteristics of this artificial lift method. Improved identification of elastomer compatibility with reservoir fluids / conditions; improved prediction of stator-rotor fit over time; and reduction of top rod / drivehead breaks are the remaining challenges to improving PCP performance.
Single-Phase Model for ESP's Head Performance
Authors: Sun Datong , Prado Mauricio 
Published: December 2007

Abstract
This paper presents a new incompressible single-phase model for ESP's head performance. Sachdeva (1988) and Cooper (1966) developed models for ESP channels [1, 2] and for inducers [3], respectively. The model presented in this paper is based on one-dimensional approximation along an ESP channel. The new derived pressure ODE (Ordinary Differential Equation) for frictionless incompressible flow is consistent with the pump Euler equation. New models for pump frictional and shock losses have been proposed. Finally, a comparison between the predicted pump performance and the pump performances from Affinity Law for different rotational speeds is presented. The single-phase model can predict ESP performance under different fluid viscosities and also is the basis of gas-liquid model for ESP's head performance.