bluuebunny/crossref_metadata_2025_split huggingface dataset:
Integrating Microseismic Monitoring With Well Completions, Reservoir Behavior, and Rock Mechanics
Authors: Warpinski N. R. 
Published: June 2009

Abstract
Microseismic monitoring has proved to be a valuable technology for assessing and optimizing hydraulic fracturing in a host of tight sand and gas shale reservoirs. Parameters such as fracture length, height, azimuth, and asymmetry are readily identified, but this technology can also be useful for understanding staging effectiveness, stimulated volume, complexity and network growth, natural fractures, stress azimuth and changes in that azimuth, fault interactions, and reservoir behavior as a result of the treatment. Various published data sets are examined to show how both quantitative and qualitative information about the fracturing behavior, completion effectiveness, and reservoir behavior can be usefully extracted from the microseismic data. Examples will include both vertical and horizontal wells, relatively planar and network fracture systems, various staging and diversion techniques, and faulted and naturally fractured reservoir response.
The Effect of Micro-Emulsions On High and Low GOR Gas Wells
Authors: Crafton J. W. , Penny G. , Burkett B. 
Published: June 2009

Abstract
An extensive, on-going investigation into the effectiveness of a micro-emulsion (ME) as a stimulation fluid additive is being conducted. Results from a population of 114 wells and 498 stimulation stages of hydraulic fracture stimulation provide the basis for this report. As part of the basis for the performance analysis, twenty four of the wells are producing from the Lance interval in the northeastern Pinedale Anticline area of the Green River Basin, Wyoming. The remaining 90 wells produce from the northern Denver-Julesburg Basin Codell and Niobrara formations. In both data sets about half of the wells had 1.5 gallons of ME per thousand used throughout the fracture stimulations, but at no other time during in-well operations. The stimulation fluid systems in the remaining wells contained no similar interfacial tension / surfactant system. Based on the performance matched reservoir properties and degree of effective stimulation, these comparisons and other performance metrics were used to assess the potential benefit arising from using ME. The determination of potential benefit was assessed using classical statistical methods to ensure that the interpretation was as unbiased as possible. From that analysis, there is distinct and clear benefit to be gained from using the micro-emulsion to facilitate placing the fracture stimulations, to increase effective fracture length and especially to increase hydrocarbon recovery from the wells in which the micro-emulsion system is used.
Integrating Solid Expandables, Swellables, and Hydra Jet Perforating for Optimized Multizone Fractured Wellbores
Authors: Durst D. G. 
Published: June 2009

Abstract
Growing energy demand is leading the industry to re-evaluate resources found in challenging conditions such as unconventional formations. Cost-effective development of these resources depends upon strategic application of advancing production solution technologies. To enhance production and improve recovery processes, more efficient perforating and fracturing methods have evolved along with advancements in wellbore production hardware via use of solid expandable tubulars or combinations of solid expandable and conventional tubulars.
Expandable technology applied as a completion/production string provides an optimized or customized wellbore that can facilitate increased fracturing rates, resulting in improved conductivity and enhanced hydrocarbon production. A fully expandable or combination system with standard casing can provide an integral component in either new wells or re-entry wells where low-permeability reservoirs, such as those characteristic of unconventional formations, require isolation and separation for pinpoint hydraulic fracturing.
Although successful stimulation is routinely attained from hydraulic fracturing, ancillary downhole tools, such as conventional completion equipment, often compromise results by restricting flow and affecting pressure performance. Solid expandable swellable systems can optimize the fracturing parameters by maintaining larger diameters and providing positive seals for selective multi-zone isolation purposes. These production systems consist of expanded sealing sections in combination with expandable or conventional intermediate tubulars utilizing premium connections thereby providing a superior completion solution for mechanical diversion.
Right-sizing the wellbore to the reservoir can provide operators significant cost savings, even more so during these economic times. Utilizing larger diameter expandables in the horizontal wellbore allows operators to first optimize the fracture program to the potential of the reservoir then develop the well program to accommodate the fracturing rates and volumes as well as the surface pumping facilities. This can result in slimmer surface and intermediate sections at much lower cost without compromising the overall stimulation completion program nor planned production and recovery.
This paper will discuss the integration of expandable systems with other technologies and cite case histories to illustrate the effectiveness of solid expandable systems in enhanced production and fracturing applications.
Coiled Tubing Deployed Resin Treatment Remediates Proppant and Formation Sand Flowback in High-Temperature Wells: A Field Study in South Texas
Authors: Durkee M. , Peak Z. T. , Montes M. B. , Nguyen P. D. 
Published: June 2009

Abstract
Flowback of proppant and formation sand can often become problematic for operators because the solids cause equipment damage, costly cleanup treatments, and potential loss of production. These flowback problems are often compounded in severity in wells with high temperature and high pressure. Operators seek reliable solutions to (1) eliminate the need for frequent remedial cleanouts and surface equipment replacement and (2) to maximize revenues by increasing and maintaining production rates.
This paper presents a field case study that discusses the remedial treatments and knowledge gained from more than 30 wells in south Texas where proppant and formation-sand flowback problems have been encountered by the operator. It also discusses the development and treatment processes using low-viscosity consolidating agents to be applied in the treatments. Examples presented illustrate how the problems were successfully overcome in these high-temperature wells.
Field results indicate that more than 90% of these consolidation treatments have effectively stopped the flowback of proppant and formation sand while allowing the production rates of the wells to be increased. These treatments have drastically decreased the number of workovers compared to the period before their treatments, or compared to the offset wells in the same field where consolidation treatments were not performed. This study demonstrated that an effective coating of a curable resin on the proppant and formation sand close to the wellbore is necessary to help maximize the consolidation bonding between grains within the pack while minimizing any reduction of its permeability.
This new remedial-treatment process greatly enhances the effectiveness of fluid placement into the propped fractures, regardless of the number of perforation intervals and their lengths and without mechanical isolation between the intervals. The simplicity of treatment helps make remediation economically feasible, especially in wells with marginal reserves.
An Advanced Injection System For Chemical Activation Of Blast Furnace Slag Cement
Authors: Brooks Fred A. , Lang William J. , Daves Thomas W. 
Published: June 2009

ABSTRACT
Granulated, hydraulic Blast Furnace Slag (BFS) is finding application as a well-cementing material mixed either in water or in water-based drilling fluids. Unlike Portland cement-based systems, which have been used for well cementing for almost a century, the BFS formulations require chemical activators to achieve set for most well conditions. The most widely used activators are soluble inorganic alkalies.
This paper reports the design, development, and testing of the Proportioning Injector Unit (PIU).This device is placed in the flow line (between the drilling rig mud pumps and the cementing head) when using BFS to cement casing in a well. The PIU includes an inline flow meter to continuously monitor the flow rate of a BFS cement lacking one or more of the activators. The data from the flow meter allows a programmable controller to operate the positive displacement pumps ensuring a precise, predetermined amount of activator solution is injected into the stream prior to the now activated BFS cement entering the cementing head.
A prototype PIU has been fabricated, yard tested, and used for a test mix in the field. It is now available for use in conjunction with drilling rig mud handling equipment to cement casing in wells.
Electrical Motor Power Measurement as the Key for Optimized Rod Pumping
Authors: McCoy J. N. , Podio A. L. , Ott Russ , Woods Mike 
Published: June 2009

Abstract
The development of accurate digital measurement of instantaneous powerduring a pump stroke has made possible a very quick and detailed analysis ofthe efficiency of the pumping system. The efficiency is then used as thebenchmark for determining whether a complete well performance analysis iswarranted from the standpoint of making best use of personnel and economicresources to increase oil production.
In addition, power measurement provides direct information about liftingcost per barrel of fluid and barrel of oil produced, electrical and mechanicalloading of the prime mover, peak power demand, power factor and minimumrequired ratings. These results give operating personnel information regardingpotential problems and give to management a complete picture of thedistribution of pumping costs.
The power measurements are also converted, by the software, to instantaneoustorque and presented as continuous torque curves for the upstroke anddownstroke. This allows determination of the existing level of counterbalanceand provides the most rapid and accurate method for counterbalance adjustmentto achieve lower torque loading on the gear box and reduced energy utilization.One of the principal advantages of this balancing method is that counterbalanceadjustment can be made without need for an accurate description of the pumpingunit's geometry which is often unknown or inaccurate. The effect ofcounterweight displacement on torque and power is observed immediately byrepeating the power measurement after relocating the counterweights.
This paper presents a series of case studies showing the Application ofpower measurement to a variety of pumping systems and components, includingconventional, Mark II, Rotaflexunits and high efficiency motors.
The Physics of Cyclic Deformation and Applications to Coiled Tubing
Authors: Rolovic R. D. , Tipton S. M. 
Published: June 2009

Abstract
The tendency for coiled tubing to grow in diameter due to internal pressure and elongate permanently due to axial loading has been the focus of recent research. These permanent deformations occur in spite of the fact that nominal stresses due to internal pressure and axial loading are well within elastic limits in both the hoop and axial directions. Bending strains that are well into plastic regime are responsible for ratcheting mechanisms in coiled tubing. Progressive plastic deformation can occur under a combination of steady (internal pressure) and cyclic (bending and/or axial) loading. A portion of plastic strain, not recovered in each cycle, may lead to large accumulated plastic strains. A new analytical model capable of predicting ratcheting behavior of this type has been developed and applied to coiled tubing. The model predicted interesting trends, never before noted in the open literature, including incremental decreases in both diameter and length of a coiled tubing section during bending cycles under positive internal pressure. The accuracy of these predicted trends was validated experimentally. The success of the analytical model is based on a new incremental plasticity model that closely conforms to the physics of cyclic plastic deformation. Some elements of the new plasticity model are discussed and predictions are compared to experimental results from complex tests involving variable pressure and axial loading.
Operating in Environmentally Sensitive Areas : International Operators Perspective of Overcoming the Challenge of Waste Management in Eastern Venezuela
Authors: Twynam A. J. , Melchor A. , Page P. W. 
Published: June 2009

Abstract
BP Exploracion de Venezuela (BPV) have been operating in Eastern Venezuela since 1994 under an Operating Service Agreement with PdVSA. BPV operate in the Pedernales and Guarapiche areas which are considered two of the most environmentally sensitive areas within Venezuela. This paper discusses the design and implementation of a Waste Management Strategy having the objective of demonstrating an Integrated Waste Management system that is realistic, leaving no damage to the environment or future risks and recognised by the Venezuelan Ministry of the Environment (MARNR) as a totally acceptable solution.
The waste generated by both drilling and production activities are discussed.
The operating environments of Eastern Venezuela demand a greater investment in environmental compliance and re-quires "better than best practice" solutions to Waste Management issues. A Field Management Plan has been introduced with clear roles and responsibilities for waste handling, waste tracking and reporting systems and clear disposal options.
The model used by BP Exploracion de Venezuela will be of interest to new Operators in Eastern Venezuela, and other environmentally sensitive areas of the Globe.
Safe Techniques of the Perforation System for Oil and Gas Wells
Authors: Zhixin Wang , Junyou Chen , Xianwen Dong 
Published: June 2009

Abstract
The perforation field all over the world has been puzzled by the difficult question that the perforating system goes off on the ground while doing oil and gas well perforating operation. Besides necessary safety education and strictly operating rules, regulations & procedures, the perforating operations should be guaranteed by systematic and necessary safety techniques. This paper analyzed the non-safe factors existed in the perforating operations in the aspect of the dangerous source, safety control and the reliability evaluation of the perforation system, and presented the corresponding countermeasure to each links. All these countermeasure and measurement have been tested and successfully applied for over ten thousands times in more than 4000 wells, goods results have been obtained.
Successful Use of a Synthetic Drilling Fluid in Eastern Venezuela
Authors: Twynam A. J. , Shaw D. , Heard M. , Wilson K. J. 
Published: June 2009

Abstract
Increased drilling performance and low mud consumption rates have made it economical to drill with an environmentally responsible, synthetic drilling fluid in the Orinoco River Delta, Eastern Venezuela. Initially, water based muds were used. Troublesome shales and claystones, coupled with complex tectonic stresses, were cause for numerous hole cleaning and wellbore instability incidents. It was decided to utilize an invert mud with the knowledge that this would inhibit the swelling mechanism of shales and reduce the hydraulic invasion of filtrate into the shale. A synthetic system was chosen for environmental impact concerns, even though the rigs were operating at zero discharge of drilling wastes.
This paper details the reasons for the use of a synthetic based drilling fluid and discusses the planning and implementation of the enhanced drilling fluid programme which ultimately led to a step change in drilling performance. The paper also discusses the utilisation of an Alliance Team and the various Alliance networks to deliver solutions to the challenges faced.
The results have been excellent: zero spills, improved drilling performance and world class consumption rates. Hole stability has greatly improved with mud densities identical to those previously used for near vertical wells. Since introduction of synthetic fluids, mud density profiles are designed relative to balancing pore pressures, as the rock/water base drilling fluid chemical interaction factor has been reduced.
The benefits to operations have been faster completion of wells, lower drilling costs and the ability to plan and operate increasingly difficult wells to better meet demands for production.
A Mortality and Morbidity Study in the Petrochemical Community in Trinidad and Tobago
Authors: Coombs Victor 
Published: June 2009

Abstract
The Caribbean was the first "Global Village", Sugar Plantation doctors were the first Occupational Physicians in the region. This Mortality Study is the first reported study on mortality among petroleum workers in the English Speaking Caribbean. The study population was 5000 workers and 15000 retirees of Petrotrin and its predecessor companies. 1436 death certificates were reviewed during 1979–1990. Cardiovascular diseases and cancer were the top two causes of death. A morbidity study was done in April / May 1997, also a first of its kind. 2339 patient visits made to our medical facilities were analyzed.
Cardiovascular diseases, respiratory diseases and musculoskeletal diseases were the top three conditions presenting. An overview of these two studies are presented as well as a snapshot of a stress survey.
The Use of Critical Body Residue to Predict Produced Water Impact to the Marine Environment
Authors: Rampen W. A. Rondonuwu , Sidharta Henky , Smith J. P 
Published: June 2009

AbstractProduced water discharge from offshore production facilities has been an accepted practice for many years but the environmental fate and impact of these waters is coming under increased public and regulatory scrutiny. Improvements in effluent water treatment has resulted in improved removal of suspended solids and hydrocarbon fractions, but this is against a background of increasing water volumes, a result of aging reservoirs, resulting in an increased contaminant load to the receiving environment. In addition, advances in analytical chemistry coupled with toxicity testing programs has defined a significant increase in potential adverse impact.This paper presents the results of LC50 testing for high volume discharges, determination of toxic dose based upon lipid consentrations for determination of critical body residue (CBR) and application of CBR with numerical dispersion modeling to predict acute and chronic toxicity. It was found that acute toxicity even at these volumes causes no significant impact to the environment but the effect of longterm chronic exposure need further review and testing.
Geostatistical Evaluation of QHD 32-6 Oil Field: a DRO in China
Authors: Shih Tai-chang , Yang An-Ping , Cheng Charles T. , Quan Youli , Lu Gou Fan , Wang Ben , Martin D. Lee , Hussey Eric M. 
Published: June 2009

Abstract
The QHD 32-6 heavy oil field in north-central Bohai consists of a series of stacked pay sands in the Pliocene and Miocene at a depth of 1,000 to 1,500 m. To enable the best understanding of the reservoir geology, we have performed geologic, geophysical, and petrophysical studies resulting in construction of a detailed geologic model using advanced geostatistical techniques. The geostatistics evaluation allowed the integration of well logs (as hard data) and 3-D seismic (as soft data) to derive a reliable and detailed 3-D reservoir characterization. The resulting geologic model consists of 18.7 million cells (25 × 25 × 1 m in size), with porosity and permeability values determined for each cell by cokriging seismic attributes to well-log data. The geological model provided input to reservoir simulations, and facilitated the conceptual design of development drilling and production facilities.
Cryogenic Nitrogen as a Hydraulic Fracturing Fluid in the Devonian Shale
Authors: Grundmann Steve R. , Rodvelt Gary D. , Dials Greg A. , Allen Robert E. 
Published: June 2009

Abstract
With proper engineering, liquid nitrogen can be used safely as a hydraulic fracturing fluid. The fluid's extremely cold temperature (−300 to −320°F) will induce thermal tensile stresses in the fracture face. These stresses exceed the tensile strength of the Devonian shale, causing the fracture face to fragment. Because of the extreme temperatures, treated water can be used as a diverter between fracturing stages. This water freezes instantly when it contacts the first treatment zone. This paper discusses the successful application of this technology to stimulate the Devonian shale in Eastern Kentucky.
Transient Pressure Behavior of Composite Reservoirs with Moving Boundaries
Authors: El-Khatib Noaman A. F. 
Published: June 2009

Abstract
A mathematical model is developed for the transient pressure behavior in a composite reservoir-aquifer system with a moving front between oil and water causing the formation of 3 zones. The diffusivity equations for the three zones are coupled with the frontal advance formula of the moving boundary of the water-oil interface. The equations are solved simultaneously in Laplace space using the finite difference method. An iterative procedure is used to estimate the location of the moving front. The solution is then inverted numerically into the real time space using the Stehfest algorithm. The effects of reservoir size, aquifer size, production rate, mobility ratio, skin and wellbore storage are investigated. Results in terms of dimensionless pressures and logarithmic dimensionless pressure derivatives as functions of the dimensionless time are presented. The case of pressure buildup is also investigated.
History and Economics of Flooding a Fractured Lime Reservoir
Authors: Ervin P.S. 
Published: June 2009

Abstract
Kirk field is located approximately 3 miles east of Gorman and 23 miles southeast of Eastland, in Eastland and Comanche counties, Texas.
Engineering studies of waterflood possibilities were commenced in the latter part of 1948. Recommended pilot water injection operations were started in May,1949.
The field was unitized in January, 1950 with all production from Sept. 1,1949 distributed on participation factors based 25 per cent on wells and 75 percent on acre feet.
The producing zone is the lower Marble Falls lime of Pennsylvanian age. Porosities and permeabilities are very low. Oil gravity is 41°API and viscosity of the reservoir fluid is relatively low.
Primary recovery to Aug. 1, 1949 was 643,631 bbl, at which time field production from 103 wells was 80 BOPD at very high GOR. Reservoir pressures were down to 350 psig from 1,300 psig original.
The productive area covered approximately 3,000 acres with estimated average thickness of 11 ft. Primary recovery was estimated to be not over 5.4 per cent of the original oil in place.
Pilot water injection operations indicated efficient waterflooding operations could be conducted although the trend of water movement from the seven initial water injection wells indicated the presence of fractures.
Proposed line drive operations were changed to modified five-spot pattern operations. Subsequent drilling and coring proved the presence of vertical fractures.
Injection of 8,325,000 bbl of water to the end of 1955 resulted in the recovery of 888,000 bbl of oil, or 9.4 bbl of water injected per barrel of oil produced.
Investment of $196,000 resulted in the production of $2,440,000 worth of oil. Deduction of investment, and operating costs of $547,000 over 76 months resulted in a gross revenue to all, interests of $1,700,000 from the waterflood operation or almost $9.00 per $1.00 invested.