bluuebunny/crossref_metadata_2025_split huggingface dataset:
A Basic Study of the Interaction of Steam, Hot Water and Oil in Water Emulsion
Authors: McKay A. S. , Redford D. A. 
Published: June 2014

ABSTRACT
Eighty percent quality steam at 200°C and 200 psi was injected into a horizontal cylindrical simulator 100 cm in length and 25 cm in diameter with a frac sand communication path along the central axis. Injection and production fluid temperatures and pressures along with the temperatures of 35 thermocouples located in the porous sand were recorded every five minutes. Whenever steam is present the thermocouple temperature can be converted to the saturated steam vapor pressure which is also the same as the fluid pressure regardless of the amount or quality of the steam. It was possible to plot steam profiles at various times which were the dividing line between fluid that contained very little steam and fluid that was 100% hot water and bitumen. Most of the bitumen was mobilized in the hot water zone between the steam profile and the 120°C profile. The 20% oil cut oil in water emulsion that was produced through the communication path had sufficiently high viscosity to divert the injected steam and hot water into the cooler immobile bitumen tar sand zones.
This experiment has been very helpful in developing improved thermal processes for the in situ recovery of bitumen and heavy oil.
New Relationships for Slug Sizing in Radial Two-Phase Displacement
Authors: Allen Elise 
Published: June 2014

ABSTRACT
An experimental study was made of the unconfined radial displacement of miscible Newtonian and non-Newtonian fluids in a Hele-Shaw cell and a narrow packed radial cell. The results show that viscous fingering in uncnnfined radial flow is not simply a function of the mobility ratio for a given set of displacement conditions. Both the displacement efficiency and the dimensionless size of the dispersion zone are power-law functions of the displacement distance for Newtonian and non-Newtonian fluids. The instability of non-Newtonian displacements is a strong function of the fluid rheology, and of the degree of heterogeneity in the porous medium. The ratio of the dispersion zone width to the mean radius of the interface can be estimated within ± 80 percent from Koval's theory for flow in a slit. However, the results for flow in the packed cell suggest that the appropriate slug size for these displacements may be substantially underestimated from the existing relationships (by up to 600 percent). New equations are proposed to describe the fingering behaviour in radial flow, and a correlation is provided for determining the displacement efficiency of Newtonian fluids in a slit (fracture).
Polymer-Enhanced Foams Part 1: Laboratory Development And Evaluation
Authors: Sydansk Robert D. 
Published: June 2014

SUMMARY
A laboratory study was conducted to identify pertinent properties and features of polymer-enhanced foams (PEFs). In addition, initial development of acrylamide-polymer oil-recovery PEFs was completed. Polymer addition to the aqueous phase of conventional foams resulted in foams of enhanced viscosity and stability. Based on findings of this laboratory study, PEFs appear to be attractive conformance-improvement fluids and attractive mobility-control fluids for use in naturally fractured reservoirs. The acrylamide-polymer PEFs promoted exceptionally high effective viscosities and were much more stable than conventional oil-recovery foams. Effective viscosities of the PEFs were comparable to the viscosities of the polymer solutions from which the PEFs were derived. PEFs exhibited shear-thinning viscosity behavior which makes them attractive for use as mobility-control fluids.
The following parameters relating to PEFs were studied: polymer properties and concentration, surfactant types and concentration, aqueous phase viscosity, absolute pressure, foam quality (volume fraction gas), gas type, stability in glassware, rheology and the effect of shear, critical pressure gradient for flow, and briefly, temperature and brine makeup chemistries. Stability of PEFs in glassware was much better than that of counterpart conventional foams. PEFs were successfully formulated over a broad range of foam qualities, and the viscosity performance of the PEFs was highly insensitive to foam quality. A PEF was more efficient than brine or two polymer solutions at displacing a viscous oil (25:1 oil:water viscosity ratio) in an ideal fracture model. Much of the experimental work involved constant-differential-pressure flooding experiments performed in high-permeability sandpacks. PEFs were successfully formulated with nitrogen, carbon dioxide, and methane as the gas phase.
The study was limited to PEFs for application within fractures of naturally fractured reservoirs and to PEFs that are to be generated above-ground prior to injection. Only the addition of acrylamide polymers to foams was considered. A large majority of the PEFs were formulated with alpha olefin sulfonates as the foaming surfactant.
The Impact of 3D Seismic, New Well Data, and a Review on the Development Plans for a Mature Field
Authors: Chung K. S. , Holtam V. R. 
Published: June 2014

Abstract
Peak production from the Baram Field was ca. 60,000 b/d in 1974. However, ly 1987, production had declined to below 10,000 b/d. In 1987, the Baram Field Joint Venture Study Team identified significant scope for further development, with 132 MMstb of reserves proposed for development from a senes of new platforms and revisits to existing platforms. To firm-up diese reserves, 3D seismic was acquired over the whole Baram Field in 1988.
Based on the new 3D seismic based maps and new data from recently woiked over wells, a review of reserves was carried out and the scope for further development revised. Based on this woik, significant additional reserves were identified, while the scope of individual projects also changed significantly. The reserves planned for development now stand at 191 MMstb, while the number of proposed new platforms has been reduced.
This paper discusses the 3D seismic data set and Interpretation problems as well as the impact of the 3D seismic on the structuie maps. The review of reserves is discussed, including the performance re views and simple Simulation studies. The paper shows how 3D seismic together with new well data and a review of the performance can have a significant impact on the development plans for a mature field.
Statistical Secondary Recovery Model
Authors: Barbieri Roberto R. 
Published: June 2014

Abstract
A secondary recovery model has been developed to predict waterflood performance for different reservoir properties and design conditions. A causal model based on simple and multiple regression equations uses eight input variables to estimate injection rate, ultimate secondary reserves, response time and yields peak oil rate, peak year and the production profile as a function of time. It is used for secondary reserve booking, to develop production profiles for project economics and authorization for expenditures and to assess technical risk by means of the simulation technique.
State-Of-The-Art In The Matrix Stimulation Of Horizontal Wells
Authors: Frick T. P. , Economides M. J. 
Published: June 2014

AbstractHorizontal wells have created a number of new challenges including the appropriate reservoir selection, drilling and completion techniques and, recently, stimulation.The ever lengthening horizontal sections pose considerable problems in fluid distribution, required stimulation fluid volumes and optimization of stimulation versus completion. The pre- and posttreatment productivity indexes, and stimulation execution requirements are the essential elements of the technology presented here.
Tracer Injection Simulations by Finite Element Methods
Authors: Loula A. F. D. , Guerreiro J. N. C. , Ribeiro F. L. B. , Landau L. 
Published: June 2014

Abstract
In this paper we describe a methodology to simulate tracer flow, using finite element methods. After time domain discretization, classical Galerkin's method is used to approximate the pressure equation and then the velocity is accurately calculated through pressure gradients, Darcy's law and a post-processing technique. To solve the concentration equation, we use a streamline upwind Petrov-Galerkin (SUPG) method in two steps. An h-adaptive finite element technique is also adopted. Numerical results are presented illustrating the applications of these techniques to a five spot geometry.
A Multigrid Procedure for Local Grid Refinement in Oil Reservoir Simulation
Authors: Rodrigues J. R. P. , Dickstein F. 
Published: June 2014

Abstract
We discuss local grid refinement procedures for reservoir simulation, including local timestepping, which means the use of different time step sizes in the coarse and refined regions. A non-linear multigrid algorithm is proposed for solving the coupling between coarse and fine meshes. This approach does not need to solve for matrices with complex structure, it does not employ any relaxation parameters, it is well suited for parallel processing and it can be easily implemented in existing simulators.
The proposed techniques were implemented in a black-oil simulator and tested in complex problems described in the literature. The results show the ability local grid refinement has to model the behaviour in the vicinity of wells. The coupling algorithm has shown to be robust and efficient, allowing a significant reduction in CPU time when compared to regular and fine meshes. The local timestepping procedure has shown to be attractive specially in cases where the number of grid blocks in the coarse mesh is large when compared to the refined regions. This situation is typical of field studies.
Multiphase Transportation of High Waxy Crudes
Authors: Rai R. , Sarkar B. , Dalai V. 
Published: June 2014

AbstractThere is a general concern in the oil industry regarding the flow of crudes at temperatures below the pour point. However, this concern is not valid as long as adequate pressure is available to maintain the continuous flow. Practically, pumping of waxy crudes below the pour point is quite common for the transportation of such crudes. Multiphase waxy crude is associated with dissolved and free gas; water can be present either as free water or in emulsion form; and gas-liquid flow pattern such as slug flow may occur with turbulent mixing. All these tend to decrease the congealing of the waxy crudes.An analysis of a case history has been carried out on the possibility of congealing of high waxy multiphase flow lines considering above governing parameters. The analysis includes normal operating condition as well as shut down and start up of the pipeline.The analysis confirmed that the congealing of crude in pipeline should not be concluded simply based on the pour point of the dead crude. This is even more relevant in the case of multiphase transportation. Based on the recommendations for the present case, a marginal offshore field of India was put on production and is producing since then without any major problem. This has eliminated a recurring cost of US $ 0.4 million per year on chemical treatment apart from capital cost on other requirements of chemical dosing.
Workforce Participation in Safety Case Preparation
Authors: Forrest J. E. , Reisz J. D. 
Published: June 2014

Abstract
The requirement in the United Kingdom for Safety Cases to be prepared and submitted stemmed from the Cullen Inquiry into the Piper Alpha disaster. The Safety Case is the means for an operator or owner of an installation to demonstrate how safe design and operation is achieved. An important part of the preparation process is to consult relevant members of the workforce.
This paper discusses how the workforce have been involved in the preparation of Safety Cases. The experience gained in submitting Safety Cases for 9 onshore and offshore installations over the last 2 years is covered with particular emphasis on the role played by the safety committee system, plant and field personnel (staff and contract) and line management. The installations range from large manned oil and gas platforms and an associated onshore gas processing plant, to small single well normally unmanned gas platforms.
The main benefits of workforce involvement have been found to be in the participation process itself. This leads to a higher level of workforce "ownership" of the Safety Case. It is concluded that this process has helped to achieve even better workforce communication, understanding and co-operation on safety issues than in the past.
Lessons Learned in a Large Full-Field Simulation Study
Authors: Williams M. A. , Toronyi R. M. , Bu-Hulaigah E. H. 
Published: June 2014

ABSTRACT
This paper presents a retrospective on the building of a combination vertical front-tracking and energy model. This effort involved the development of a new geologic description and the construction and validation of a full-field model incorporating coning and surface facility simulation. This was the most complicated and detailed model in the 35 years of numerical simulation on the Safaniya reservoir and contained 61,257 active grid cells and 500 wells with over 2,000 completions. This model represents a fully-integrated geologic and engineering approach, employing all core data, openhole and pulsed neutron well log analyses, sedimentological interpretations, RFT and flowmeter results, and pressure buildup tests to provide the best means available to capture reservoir behavior on a field-wide scale. This paper presents the lessons learned through this extensive simulation project.
Optimized Electric Submersible Pumping to Extend Economic Oil Production in a High Water Cut Environment
Authors: Galles D.J. , Larson J.B. 
Published: June 2014

Abstract
The economic life of the Equity Oil Company operated lease in the Ashley Valley Field of Uintah County, UT has been extended significantly from efficient use of electric power, Early efforts to reduce power consumption inefficiencies included replacement of flowlines to lower surface backpressure, installation of a central capacitor bank to eliminate power factor penalty payments and a well respacing project. This paper shall focus on recent efforts concerning submersible pumping optimization including the use of increased efficiency stage and motor designs and proper equipment selection to operate at maximum efficiency.

Operating Environment
The primary reservoir in the Ashley Valley Field is Weber sandstone of Pennsylvanian age at an average depth of 4,200 ft. The Ashley Valley Field is on a northwest - southeast trending anticline located in the Uintah Basin of northeastern Utah. The field was discovered in October, 1948 and is recognized as the first commercial oil discovery in Utah. A structure map is presented as Figure 1.
Initially, all wells flowed and were essentially free of water. No initial gas cap was present in the reservoir. The active fresh water drive resulted in the installation of submersible pumps on the Equity lease in 1960. Production performance is presented as a water-oil ratio (WOR) versus cumulative production plot in Figure 2. Average daily production is currently 85 BOPD and 35,100 BWPD from four wells. Produced fluids from all wells flow into a 3,000 bbl gunbarrel separation tank and through a series of retention pits for final separation. Chemical injection at the wellhead also aids in separation of oil from water. The discharge from the final retention pit is a source of agriculture irrigation water. Additional operating environment data is provided as Table 1.

Life Expectancy and Failure Mode of ESP's
Field History/Failure Modes. A field failure history quantifies run times, operating conditions and failure modes in Tables 2 and 3.
Natural Controls on NORM in Produced Water from Texas Reservoirs
Authors: Fisher R. Stephen 
Published: June 2014

Abstract
Naturally occurring radioactive materials (NORM) in produced water; sludge, and scale from Texas oil, gas, and geothermal wells increase concerns for worker safety as well as costs for handling and disposal. We combined published data, new analyses, and geochemical modeling to explore geologic, geochemical, and geographic controls on this radioactivity.
NORM are caused primarily by 226Ra and 228Ra, the alpha-decay products of 238U and 232Th, respectively, in water and barite (BaSO4) scale. Local variations in reservoir lithology are a major control on NORM levels because of the geologically short half-lives of the Ra isotopes, slow basinal fluid-flow velocities, short transport distances during reservoir production, and the naturally heterogeneous distribution of U and Th in reservoir rocks. High salinity in produced water primarily controls Ra mobility in solution. Formation water composition and reservoir temperature determine the type and amount of scale that can form. Scale mineralogy and Ra/Ba and Ba/SO4 solute ratios in turn determine the Ra activity of scale. Analysis of our data base reveals several associations of NORM activity with reservoir and formation water characteristics. These associations can be used to predict NORM levels at the play, field, and reservoir scale.
Reservoir Management: Principles and Practices
Authors: Al-Hussainy Rafi , Humphreys Neil 
Published: June 2014

Summary
Reservoir management is a method that seeks to maximize the value of a hydrocarbon asset. However, different companies and authors have differing approaches to reservoir management, and no generally accepted definition of this activity exists within the industry. This paper reviews some of the origins of reservoir management techniques and provides an overview of reservoir management principles. Reservoir management is directed toward maximizing the value of a hydrocarbon asset. The value of any reservoir is defined differently by different people at different times. To develop a reservoir optimally to maximize its value, the exact meaning of "value" must be clearly understood.
Norne Field Development - Fast Track From Discovery to Production
Authors: Steffensen Ivar , Karstadt Per Ivar 
Published: June 2014

Summary
The Norne Field was discovered in December 1991, and is one of the largest oil discoveries on the Norwegian Continental Shelf the last decade. In order to improve economy and maintain momentum in the development of the field, a novel approach of managing large and complex projects was initiated. This included amore integrated approach, with parallel execution of activities, standardisation and close relations to contractors, licence partners and authorities.
This paper review the reservoir description and development, the concept evaluations and the new approach to project management.

Introduction
The Norne Field is located in the blocks 6608/10 and 6508/1 in the Nordland II area of the Norwegian Continental Shelf. The field is located 200 km from the shore and 85 km northeast of the Heidrun Field (Fig. 1). The water depth in the area is 370 to 390 metres.
The Norne Field was discovered in December 1991 by well 6608/10-2. The discovery well contained a total hydrocarbon column of 135 metres; a 110 metresoil column with an overlying gas cap. An appraisal well, 6608/10-3, was drilled on the northern part of the Norne structure early 1993. The well confirmed the results from the discovery well, and proved the extension of the field to the north. Well 6608/10-4 was drilled in a structure 2-3 km east of the Norne Field early 1994, and discovered a minor oil accumulation.
Time from discovery to production and investment costs are major factors influencing the economy of a field development. In the past, the time from discovery to production for field developments comparable to the Norne Field(water depth, reserves, etc.) have been 8-10 years. The Norne development project was established in the spring of 1993 with objectives to minimize time from discovery to production, and to reduce the investment costs with 30-40%compared to the current established level in Norway. To achieve this, a new approach to project management was required.
Application Of The Technique Of Multi-Fracture Fracturing Using Diverting Agent
Authors: Dingxiang Xia , Jiaqi Wang , Xiuchen Wang , Ximin Chen 
Published: June 2014

Abstract
In Daqing Oilfield, since 1988 1524 oil wells have been fractured by this technique. This is 21.4 percent of all fractured oil wells. The average oil production improvement of each well is 15.0 t/d, a 1.5 fold increase over conventionally fractured wells. The cumulative oil production improvement is 340.3 × 104 tons 203 water wells were fractured by TMFUD, 33 0 percent of all the fractured water injection wells The mean water injection improvement per day is 80.8 m3/d, and the cumulative water injection rate is increased by 146.6 × 104m3. The multifracture fracturing technique can be used to stimulate low permeability thin interlayers and as many as 6 to 9 independent sub-layers without moving the string.
Progressive Production Technology in Complicated Dispersed Small Oil and Gas Fields
Authors: Tiesen Sun , Shulin Su , Houfa Liu , Shanbin Du 
Published: June 2014

Abstract
Producing experience in complicated, dispersed small oil and gas fields in the west peripheral area of Daqing oilfield has led to development of a system of progressive production technology. Experience shows that this technology system is feasible and of good practical value to the production of a complicated small oilfield.
Pilot Test of Water Alternating Gas Injection in Heterogeneous Thick Reservoir of Positive Rhythm Sedimentation of Daqing Oil Field
Authors: Baojun Feng , Xingjia Du , Cai Yu 
Published: June 2014

Abstract
Immiscible WAG injection was successfully used to enhance the oil recovery in the thick, heterogeneous reservoir in the east of Beier area of Daqing oil field. After a five year test period, the water cut is basically stable and production is continuously increasing. The recovery factor is now more than 3% higher than the ultimate recovery factor by water injection, and ultimate recovery is predicted to be more than 8% higher. Changes have taken place in the water entry profile of the injection well. Gravity segregation occurs in the reservoir. Areal sweep conditions are improved and the thickness of liquid production increased.
Well Logging Interpretation Method for Oil-Water Two Phase Flow
Authors: Yulong Wang 
Published: June 2014

Abstract
The production profile can be obtained with a continuous flow meter and a gradiomanometer. Slip and other factors in the vertical string for two phase (oil-water) flow, affect the data and make it very difficult to interpret. To solve this problem, studies were made in a simulation well of the relationship between the rotary speed of the spinner and the water holdup, and the ratio of the apparent velocity to the average fluid velocity and water holdup. Four relationship charts and interpretation programs were developed A total model of the simulating experiment was built, which can interpret multiple zone oil/water production rates to draw their profile map, and quantitatively interpret oil bubbles moving upward, and interpret the reverse rotation of the spinner in the vertical string. The data obtained from 20 wells show that the method has high resolution so that low producing layers can be detected and quantitatively interpreted. Also, intra-formationaJ interpretations for thick formations can be made. In conjunction with the water intake profile of the surrounding injection well, a plot of water-injection versus oil-production can also be drawn.