bluuebunny/crossref_metadata_2025_split huggingface dataset:
Offshore Operating Costs for Marginal Fields: "Selecting The Best Operating Strategy"
Authors: Steube Chuck 
Published: December 2007

Abstract
This paper outlines a methodology for the foundation and selection of an operating plan for FPSQ field developments. This methodology can also be applied to any onshore or offshore oil or gas field development. The primary consideration for this methodology involves integration of all involved parties during the conceptual engineering phase of field development. This should include the following:
Company integration between the different technical disciplines such as ( Drilling, Engineering both Reservoir, Well and Process, Operations, and others such as Marine or Pipeline) Integration of Partners within the project team Integration of Regulatory Bodies early on in the development phase Integration of Contractors to identify the potential for shared service agreements which increase equipment utilization and result in significant cost savings
This approach lends itself to viewing the project from a complete field life cycle. The methodology then can be used as a road map to identify operating cost ranges and the most cost-effective approach for field development.
IMPES Stability: The CFL Limit
Authors: Coats K. H. 
Published: December 2007

Abstract
This work considers cocurrent, three-dimensional, single-phase miscible and two-phase immiscible, hyperbolic flow in a general grid, structured or unstructured. A given grid block or control volume may have any number of neighbors. Heterogeneity, anisotropy, and viscous and gravity forces are included, while tensor considerations are neglected. The flow equations are discretized in space and time, with explicit composition and mobility used in the interblock flow terms (the Impes case).
Published stability analyses for this flow in a less general framework indicate that the CFL number must be &lt; 1 or &lt; 2 for stability. A recent paper reported non-oscillatory stability of one- and two-dimensional Buckley-Leverett two-phase simulations for CFL &lt; 2. A subsequent paper claimed to predict this CFL &lt; 2 limit from a stability analysis. This work gives a different reason for that stability up to CFL &lt; 2.
This work shows that the eigenvalues of the stability matrix are equal to its diagonal entries, for any ordering scheme. The eigenvalues are in turn equal to 1-CFLi, which leads to a conclusion of an early paper that CFL &lt; 1 is required for non-oscillatory stability. CFL values between 1 and 2 give oscillatory stability. In general, our Impes simulations require the non-oscillatory stability ensured by CFL &lt; 1.
Full-Tensor Multiphase Flow Simulations With Applications to Upscaling and Discrete-Fracture Models
Authors: Yang Yi-Kun , Deo M. D. 
Published: December 2007

Abstract
The permeability tensor in three-dimensional space is given by a symmetric and positive definite matrix. Advances in reservoir characterization and geostatistics facilitate the construction of fine scale reservoir images. Some degree of upscaling is almost always required to make the problem computationally amenable. The upscaled permeabilities calculated thus are, in general, full tensor quantities. Homogenization of discrete-fracture domains also leads to full-tensor permeabilities of the equivalent permeability field. A formal infrastructure to treat full-tensor permeability field has been developed in this paper along with an understanding of the impact of such a field.
A novel co-ordinate transformation scheme is proposed where the cross permeability terms are eliminated and an equivalent diagonal-tensor permeability field is generated. The multiphase flow equations are solved using the finite-element discretization. Galerkin finite element method is employed and the model equations are solved fully implicitly.
First, it is demonstrated that full-tensor representation is necessary to preserve the flow characteristics in the fine-grid domain in both the cases. It is then shown how the computational complexity of the full-tensor simulation could be reduced using the transformation scheme. The novel transformation scheme thus offers the computational simplicity of the diagonal-tensor representation, while preserving the rigor of the full-tensor approach. The effect of using the full-tensor field from homogenized fracture permeabilities is described.
Simulation of Vertical Fractures and Stratiform Permeability of the Ghawar Field
Authors: Phelps Robert E. , Strauss Jonathan P. 
Published: December 2007

Abstract
It has long been known that well intersections in the Ghawar field show thin intervals of extremely high productivity. These can be related to high permeability layers (stratiform features) or to sub-vertical faults and fractures. This paper discusses the characterization of these features and their inclusion in field scale simulation model. All high permeability features (both matrix and fracture related) are incorporated into the "fracture" component of a dual-porosity dual-permeability simulation. Fine grid modeling is used to validate the approach and to gain an understanding of the physical processes taking place within the reservoir. Practical considerations and difficulties encountered in setting up a large-scale (16 x 17 km) sector model using the DPDP properties are discussed. Results for several runs that include 40 years of production history show that the methodology has the potential to improve simulation modeling of this field.
Integrated Modeling of Geological Heterogeneity and Fluid Displacement: Smørbukk Gas-Condensate Field, Offshore Mid-Norway
Authors: Brandsæter I. , Ringrose P. S. , Townsend C. T. , Omdal S. 
Published: December 2007

Summary
The Smørbukk Field comprises a deep, very heterogeneous reservoir with variable fluids (gas condensate to light oil). This study presents a series of sensitivity studies to evaluate the effect of different geological parameters and development options on oil production and gas oil ratio within a sector of that field. The black-oil Eclipse reservoir simulator is used to represent the gas displacing oil behavior of this rather complex reservoir. Constant production rates and pressure controls are assumed. Detailed geological models of sedimentary and structural heterogeneity were used to define reservoir simulation models with upscaled permeabilities and relative permeabilites. Displacement and transmissibility reduction across faults were explicitly modeled and compared with simpler assumptions. The main performance measure used is oil recovery and GOR at the five year production point. Important interactions between geological assumptions and fluid rates and pressures were identified and used to identify the most promising production strategy.
Takula Field: Data Acquisition, Interpretation, and Integration for Improved Simulation and Reservoir Management
Authors: King G. R. , David W. , Tokar T. , Pape W. , Newton S. K. , Wadowsky J. , Williams M. A. , Murdoch R. , Humphrey M. 
Published: December 2007

Abstract
Current reservoir characterization techniques allow for geostatistical models on the order of several million grid cells. In general, these models are developed from static data, such as open-hole log data and core data. Recent developments in reservoir characterization have allowed for the incorporation of some dynamic data, such as pressure transient data and 4D seismic data, into these geostatistical models.
During the day-to-day management of large oil fields, data are often acquired from sources other than those listed above. These data include cased-hole logs, production logs, and wireline pressure data. These data are generally acquired to aid in the design of workovers, plan profile modification programs, and perform other routine reservoir management tasks. Due to the frequency in which these data are acquired, they represent dynamic reservoir data. When these data are considered in a reservoir simulation study, they are typically incorporated during the history match phase. There are, however, instances when these data are incorporated during other phases of the study.
The Takula Field is the largest producing oil field in Angola. This paper discusses data acquisition and interpretation in the Upper Vermelha Reservoir of the Takula Field and its integration into the reservoir simulation model. What sets this case study apart from other case studies is the detail in which the "routine" dynamic data were integrated into the reservoir simulation model (during all phases of the study) and the detail in which these data are used to maintain the model. Topics to be discussed include:
Use of injection well PLT data during the history matching process (History matching of injection wells is a topic rarely discussed in the reservoir simulation literature). Integration of PLT, PNC, and C/O logs into water encroachment and CHPF (current hydrocarbon-pore-foot) maps. These maps were used during the history match phase of the study to match saturations on a flow unit basis. In addition, these maps are updated on an approximate six-month basis and provide the framework for checking measured frontal advance and simulated frontal advance during the prediction phase of the study. A novel approach of using cased-hole gamma-ray logs to monitor the flood front advancement of a peripheral waterflood. When appropriate, this method also aids in the determination of whether produced water is formation water or injected water and provides a dynamic check on the internal consistency of the reservoir zonation (i.e., internal reservoir "plumbing"). Use of wireline pressure data to estimate the tolerance in history matching static well pressures obtained from stratified reservoirs. Use of PNC and C/O log data to supplement core end-point saturation data and provide limits for end-point saturation adjustments during the history match.
Full-Field Modeling Using Streamline-Based Simulation: 4 Case Studies
Authors: Baker R. O. , Kuppe F. , Chugh S. , Bora R. , Stojanovic S. , Batycky R. 
Published: December 2007

Abstract
Modern streamline-based reservoir simulators are able to account for actual field conditions such as 3D multi-phase flow effects, reservoir heterogeneity, gravity and changing well conditions. A streamline simulator was used to model four field cases with up to 400+ wells and 150,000+ grid-blocks. History match run times were about 1 CPU hour per run with the final history matches completed in about 1 month per field. In all field cases, a high percentage of wells were history matched within the first 2-3 runs. History matching fields with a large number of wells is quite different than matching simulation models with only a few wells.
Streamline simulation not only enables a rapid turnaround time for studies, but also serves as a different yet valuable tool in resolving each of the studied fields' unique characteristics.
The primary reasons for faster history matching of permeability fields using 3D-streamline technology as compared to conventional finite difference techniques are:
Streamlines clearly identify which producer-injector pairs strongly communicate (flow visualization). Streamlines allow the use of a very large number of wells thereby substantially reducing the uncertainty associated with outer boundary conditions. Streamline flow paths indicate that idealized drainage patterns do not exist in real fields. It is therefore unrealistic to extract symmetric elements out of a full field. The speed and efficiency of the method allows the solution of fine scale and/or full field models with hundreds of wells. The streamline simulator honors the historical total fluid injection and production volumes exactly as there are no drawdown constraints, initially. Easy identification of regions that require modifications to achieve a history match. Streamlines provide new flow information (i.e., well connectivity, drainage volumes, and well allocation factors) that is not possible to derive from conventional simulation methods.
Streamlining Abandonments for Cost Reduction
Authors: Woody Fred 
Published: December 2007

Abstract
Total idle well population in the United States, both regulated and unregulated, currently is estimated to be approximately 1,000,000 wells. Conventionally, creating an inventory, and designing and implementing abandonment programs where appropriate has required substantial manpower. Today's computer software and portable hardware has created an opportunity to better design, implement and track abandonment programs. This paper discusses the development of a field available package, which allows real time delivery at the field level while generating essential reports and tracking process.
This methodology was required to meet the following criteria: Reduction of cost by 30%;Minimal reliance on production personnel;Real time delivery of progress reports; and,Prompt delivery of regulatory reports.
Implementing Waste Management Strategies
Authors: Ramnath Kelvin , Dyal Shyam 
Published: December 2007

Abstract
The activities of finding, producing and refinery petroleum, can impact the environment, and the greatest impact arises from the release of wastes into the environment in concentrations that are not naturally found. These wastes include hydrocarbons; solids contaminated with hydrocarbons and other pollutants, water contaminated with a variety of dissolved and suspended solids; a wide variety of chemicals and gaseous emissions contaminated with toxic chemicals.
The Petroleum Company of Trinidad and Tobago Limited (PETROTRIN), have developed a number of major capital intensive waste management programmes to ensure the Company's operations have minimal adverse impacts on the surrounding environment.
These programmes are: ❖Construction of three secondary waste water treatment plants.❖Conversion of barometric condensers to surface condensers at two vacuum distillation units at the Pointe-a-Pierre refinery.❖Segregation of storm water drainage from process oily waste water.❖Bioremediation of 126,000 barrels of oily wastes stored in two earthen pits at Pointe-a-Pierre refinery.❖Bioremediation of approximately 18,000 barrels of oily wastes stored in two earthen pits at Parrylands, Point Fortin oil field.❖Installation of three Sulfa-Treat plants for treatment of hydrogen sulphide gas in production operations.❖Installation of a Sulphur Recovery Unit at Pointe-a-Pierre refinery to convert hydrogen sulphide gas into solid sulphur.❖Installation of internal floating roofs at five product storage tanks at the Pointe-a-Pierre refinery.
Steps are being taken by the Environmental Management Authority to strengthen legislation in the near future. Major capital improvements in the implementation of waste management systems by Petrotrin have resulted in reduced impacts on the environment. The overall effort of these proactive programmes has been worthwhile due to the enormous increase in the understanding of our environment and the improvements being achieved.
Reducing the Environmental Impact by Replacing Chemistry with Physics
Authors: Sørgård Eirik , Villar John P. 
Published: December 2007

Abstract
The offshore E&P business is becoming increasingly focussed on environmental issues brought on in part by an increased awareness of the impact the industry has on the environment and the sensitive areas being explored. The fertile fishing waters in the Norwegian Sea are governed by some of the strictest environmental legislation that exists for offshore oil drilling. Incentives to minimize the exposure of chemicals to the environment have been sought after by operating companies in these waters. The work described within highlights advancements made in minimizing the chemical requirements for cement slurries used in such sensitive waters.
This paper outlines efforts which were put forth to not only reduce the environmental impact by dramatically reducing the requirement for chemicals but also to provide a technically superior cement slurry via capitalizing on the particle physics of the dry components in the cement blend.
HSE Issues: One Company's Effort To Continuous Improvement
Authors: Ferraro M. , Fassina P. , Blotto P. 
Published: December 2007

Abstract
ENI-Agip Division is actively working to develop processes increasingly compatible with the environment and health and safety principles, aiming at the best care of HSE aspects for all company's activities.
The effort expended to continually improve prevention and protection systems is considerable. At present, Agip Division is actively involved in projects with universities and research institutes as well as associations representing oil companies, as shown by the large number and high level of ongoing innovative and R&D projects.
A lot of activity concerns ongoing scientific research projects focused on management of consequences arising from environmental emergencies, definition of monitoring and techniques management systems for clean-up activities, coupling and uncoupling problems related to subsidence modeling and forecasting, etc. Also, the evaluation of accidental consequences after fire, explosion and blowout events is being actively followed. The same approach is adopted in the corrosion management where a combination of the estimated likelihood of failure due to corrosion and the consequence of this failure is assumed to define the level of risk.
The paper deals with all the innovative projects presently ongoing and intended to significantly improve Agip's HSE performance in the near future.
Environmental Management Plans Required for Financing International E&P Projects: From Development to Implementation
Authors: Snow B. L. , Ratliff M. D. , Clodfelter C. L. 
Published: December 2007

Abstract
Environmental Management Plans (EMPs), in addition to being good business practice, are often required by lending institutions for certain major oil and gas exploration and production projects around the world. Lending institutions requiring EMPs include the World Bank/International Finance Corporation (IFC), the Overseas Private Investment Corporation (OPIC), the Export Import Bank of the United States (Ex-Im Bank) and others.
EMPs are more than documents detailing the procedures to be used for the protection of human health and the environment. The plans will have to be implemented in the field. Therefore, effective development of these plans requires a thorough understanding of the project, which is obtained by close interaction between the various project planning groups and the EMP development team; intimate knowledge of the project environment; and familiarity with the resources available. This paper summarizes and shares experiences associated with the development and implementation of EMPs.
In-Depth Investigation of the Validity of the Archie Equation in Carbonate Rocks
Authors: Ara Talia Shamsi , Talabani Soran , Vaziri H. H. , Islam M. R. 
Published: December 2007

Abstract
Archie found an empirical equation for consolidated sandstones relating several formation parameters, such as, porosity and water saturation. Despite its common use by petroleum engineers, Archie equation is not easy to apply to carbonate rocks because formation parameters (a, m, n) are functions of changes in the pore geometry, clay content, tortuosity of the pores, as well as formation pressure. The other important issue that Archie equation fails to address is the fluid critical point for the multi-component state in which different phases co-exist. This being the case for light oil and condensate reservoirs, the straightforward application of the Archie equation in carbonate rocks has severe limitations. The Archie equation is valid only when the rock is strongly water wet and clay free, which is not the case in carbonate rocks. There is no linear or direct correlation between resistivity index (IR) and formation water saturation in the carbonate rocks. Therefore, the Archie equation cannot be generalized over the entire carbonate reservoir.
In this paper, a series of experiments is performed in order to derive the correct form of the Archie Equation that can be applied to carbonate rocks. The parameter a is further split to account for the composition, pore geometry and formation pressure. By separating these parameters, it is possible to find more precise correlation with formation resistivity and formation water saturation for carbonate reservoirs. Also derived are the correlations between resistivity and the composition of the carbonate rock as well as formation pressure. Finally, an equation is proposed for taking into account changes due to the presence of critical fluids. The generalized equation can then be applied to any fluid in a carbonate formation with varied geometry and clay content.
Codell Restimulations Evolve to 200% Rate of Return
Authors: Emrich C. , Shaw D. , Reasoner S. , Ponto D. 
Published: December 2007

Abstract
The Codell formation is a low permeability, clay rich, late Cretaceous age sandstone within the Wattenberg field of the DJ Basin. Since 1997 over 1500 Codell wells have been restimulated. Results on the past 200 refractured Codell wells using a reduced CMG polymer fluid system have yielded incremental monthly production results in excess of 1900 BOE/well or approximately 80% of the original initial production. Success of this program is believed to be the combination of stringent well selection criteria, high fluid quality control guidelines and effective operational field practices. It is believed that due to this recent success in restimulating the Codell, over 4000 additional wells within the DJ Basin may be restimulated with economic benefits.
This paper will discuss completion history of the Codell formation and how criteria from candidate selection to fluid quality may impact the success of such a program.
Sampling Volatile Oil Wells
Authors: El-Banbi Ahmed H. , McCain William D. 
Published: December 2007

Abstract
Recombined surface samples are usually used for volatile oil laboratory fluid property studies. A procedure for stabilizing and surface sampling of volatile oil wells is currently used in the industry. However, no investigation of the quality of the samples resulting from this procedure has ever been published.
Typically, during surface sampling, bottom-hole flowing pressure is less than the bubblepoint pressure of the original reservoir oil. This causes gas to form in a cylinder of the reservoir around the wellbore. Understanding the dynamics of this cylinder of gas saturation is critical to obtaining a recombined surface sample representative of original reservoir oil. It is possible to obtain a representative sample if this cylinder is stable.
This paper presents the results of a study of the sampling procedure. The effects of production rate prior to and during the sampling process were quantified using radial compositional simulation. The buildup and stability of the ring of gas saturation were examined.
Guidelines for sampling volatile oil wells is presented. It is based on comparisons of the compositions of recombined surface samples with the compositions of original reservoir oils for various producing schemes. These guideline are expected to give the best chance of obtaining a representative sample from a volatile oil well.
Factors Affecting the Performance of Crude Oil Wax-Control Additives
Authors: Manka John S. , Ziegler Kim L. 
Published: December 2007

Abstract
Crude oil producers have used pour point depressants with great success for several decades. However, chemical wax control packages can be plagued by crude oil specificity, large package treat rates, and waxy components that can be hard to apply.
This paper discusses what factors affect the performance of crude oil wax control additives and what contributes to crude oil specificity. This study investigated the effects of the wax control additives' polymer backbone, pendant chains, and molecular weight on cold flow performance. The impact of the solvents used, the extent of the packages' dilution and the effect of proper additive dosing is addressed.