bluuebunny/crossref_metadata_2025_split huggingface dataset:
Permeability Upscaling Techniques for Reservoir Simulation
Authors: Salazar M. O. , Villa J. R. 
Published: December 2007

Abstract
Upscaling reservoir properties for reservoir simulation is one of the most important steps in the workflow for building reservoir models. Upscaling allows taking high-resolution geostatistical models (107-108 grid blocks) to coarse scale models (104-105 grid blocks), manageable for reservoir simulation, while retaining the geological realism and thus effectively representing fluid transport in the reservoir 1,2. This work presents a study of the effectiveness of different available techniques for permeability upscaling and the implementation of a new technique for upscaling of relative permeability curves based on the numerical solution of a two-phase system and the Kyte and Berry method3.
The reference fine scale model considered in this study is a conceptual fluvial reservoir based on the Stanford V model4. The reference fine scale isotropic and locally heterogeneous permeability distribution was upscaled to different upscaling ratios by means of analytical (static) and numerical single-phase (pressure solver, dynamic) techniques. Two-phase flow simulations were performed on the reference fine grid and upscaled models using a comercial black-oil simulator. Arithmetic, harmonic, and geometric averages were defined for static upscaling of the permeability distribution. The dynamic upscaling process considered one-phase and two-phase upscaling. One-phase upscaling considered upscaling of the permeability distribution and two-phase upscaling considered upscaling of the permeability distribution and relative permeability curves.
Flow simulation results for waterflooding in the coarse scale model indicated relevant discrepancies with the fine grid results. Compared to fine-scale, flow results of the single-phase upscaling process indicated that the coarsest upscaled models did not match the water breakthrough times, water cut values, or well pressures from the reference model. The finer upscaled models reproduced the reference results more accurately than the coarser models. The two-phase dynamic upscaling technique implemented in this work resulted in the best match with the flow simulation results of the fine grid model. Results show that the most accurate upscaling scheme should be defined using the two-phase dynamic upscaling technique on the model with the smallest upscaling ratio.
Novel Chemistry Eliminates Post-Cleanup of OBM Filter Cakes from Openhole Laterals
Authors: Jones A. G. , Luyster M. A. , Ali S. A. , Needham W. J. 
Published: December 2007

Abstract
A key objective for any completion process is to avert troubletime and minimize unplanned events. The novel cleanup systems discussed in this paper were designed to work within the planned completion program, which means they do not need special tanks, lines, or equipment. One of the cleanup systems acts as its own spacer and can also be used to displace oil-based mud (OBM) from the wellbore. The system provides a delay so that operations can proceed and subsequently clean up the residual filter cake. The other system is a brine-based system that also provides a delay. Both have been successfully applied to production and injection wells. Developers of the systems gave consideration during the R&D process to optimizing openhole displacements. This paper discusses the engineering and chemistry of both systems with respect to providing a "delay" so the completion can proceed as planned.
System development in both cases included testing and simulations performed to meet pre-planning criteria that included the need to effectively displace the lateral section while maintaining positive well pressure during the completion phase. Other critical criteria were effective cleanup of the residual OBM filter cake and the ability to mitigate system upsets upon initial production.
Field results presented in this paper are from several recent openhole completions offshore Cabinda, West Africa, where the new cleanup systems were applied to alleviate post cleanup of OBM filter cakes. The paper also explains the engineering of the displacements, impact on the completion operations phase, and the production results.
Multizone Completion With Accurately Placed Stimulation Through Casing Wall
Authors: Hinkie Ron , Howell Matt 
Published: December 2007

Abstract
With a combination of (1) stimulation sleeves that are installed as part of production casing strings and (2) packers whose sealing elements expand by swelling when contacted by certain chemicals, operators may isolate and fracture-stimulate multiple payzones as part of the well-completion process.
The sleeve and swelling packer system (SSPS) enables accurately located, pinpoint stimulation of several payzones through the casing wall. The stimulation sleeves, rated to 10,000 psi differential pressure, can be opened or closed in a single coiled-tubing (CT) or jointed-pipe trip. Opening the sleeve permits zonal stimulation through the selected sleeve and diverts the flow through ports in the sleeve. After stimulation, cleanup is assisted by flowing all lower zones simultaneously. Sleeves can be shifted (opened and closed) (1) mechanically, (2) with a hydraulic shifting tool, or (3) by ball activation.
There is no limit to the number of stimulation and production sleeves that can be run in a single casing string. Once the well is completed, the sleeve will function as a standard production device, allowing full wellbore access. Stimulation sleeves have been subject to extensive laboratory and back-yard testing.
Augmenting the function of the stimulation sleeve is the swelling packer. This packer is also installed as part of the completion string; rubber elements bonded to the tubular portion swell on contact with oil-base drilling muds, formation crudes, and other formation liquid hydrocarbons. Packer elements will not swell in fresh water. Packer-swelling action creates a seal in open hole; swell time is adaptable to suit the environment. A summary of the swelling packer's features follows: Manufactured to any casing diameter.Slimmer pipe allows for thicker rubber.Thicker rubber allows greater swelling for higher differential pressure.Greater packer length increases differential pressure capability.Packer elements swell to seal irregular boreholes.Packer elements heal themselves after damage.Reliability of the swelling packer concept has been proven in more than 1,000 field applications.
The Beta Distribution and Its Application to Petrophysics
Authors: Gullco Robert , Anderson Malcolm 
Published: December 2007

Abstract
The Beta distribution in n-dimensions is introduced to describe the proportions of the mineralogical components existing in a certain stratigraphic interval (the porosity is included as a "mineralogical component"). The justification for doing so is empirical. The model allows the calculation of well logging parameters, such as GRma, GRsh, shale density, etc., without having to introduce them by "eye". It also allows the probabilistic calculation of the rock composition at each depth when there are more mineralogical components than logs: that is, there is a shortage of equations. In addition to this, the Beta model can be used to test the hypothesis that the relationship between any two components can be regarded as random, which should have applications in reservoir characterization.
Hydrocarbon Potential Monitoring of By-Passed Pay Zones Using TDT and CHFR Logs
Authors: Hamada G. M. 
Published: December 2007

Abstract
The ability to detect and evaluate bypassed hydrocarbon and track fluid movement in sandstone reservoir is vital in the quest to improve production and increases recovery. The main technique, which has been used for monitoring reservoir saturations, is TDT tool. But, it was hard to interpret the TDT data in the low formation water salinity reservoirs. This problem can not be solved because it is related to the theory itself of TDT measurement, which depends on salt content in formation brine.
Cased Hole Formation Resistivity tool (CHFR technique was proposed to overcome many of the pulsed neutrons tool limitations. This technique is called Cased Hole Formation Resistivity tool (CHFR). Based on the actual CHFR logs recorded through wells of studied oil field in Sinai, which are presented and discussed in the present work, a comparison study was done between the two available techniques, TDT and CHFR as methods for reservoir saturation monitoring, in addition to the results of open-hole resistivity logs as reference runs. It was found that water saturations calculated from CHFR logs were more accurate than TDT log in most of the cases, and that the quick look of CHFR logs always agrees with its quantitative interpretation, which gives the trust to relay on quick look of CHFR log, if a fast decision is required. While the quick look of TDT log was found to be very tricky, in most of the cases: often does not agree with its quantitative interpretation
Cased Hole Formation Resistivity tool (CHFR technique was proposed to overcome many of the pulsed neutrons tool limitations. This technique is called Cased Hole Formation Resistivity tool (CHFR). Based on the actual CHFR logs recorded through wells of studied oil field in Sinai, which are presented and discussed in the present work, a comparison study was done between the two available techniques, TDT and CHFR as methods for reservoir saturation monitoring, in addition to the results of open-hole resistivity logs as reference runs. It was found that water saturations calculated from CHFR logs were more accurate than TDT log in most of the cases, and that the quick look of CHFR logs always agrees with its quantitative interpretation, which gives the trust to relay on quick look of CHFR log, if a fast decision is required. While the quick look of TDT log was found to be very tricky, in most of the cases: often does not agree with its quantitative interpretation
Field Study Results Improve Squeeze-Cementing Success
Authors: Cowan Michael 
Published: December 2007

Abstract
Correlations and practices that improve squeeze-cementing success in a wide range of applications were developed from a series of field studies conducted between 1992 and 2000. The first study began with analysis of a database of 137 squeeze operations. Statistical analysis of data for successful first-attempt squeeze operations from this database identified practices and correlations that significantly improved the success rate for squeeze-cementing operations. The correlations developed from this initial data were applied in other operating areas and refined over time.
Prejob injection test data can be used to select basic cement type, recommended cement volume, and cement fluid loss based upon correlations developed from these studies. Guidelines for placement procedures and pumping techniques were developed from successful field operations.
While these practices have significantly improved success in a wide range of applications and geographical areas, squeeze cementing continues to defy standardization. The success of most squeeze-cementing operations is directly related to the skill and experience of those designing and executing the operation.
These practices are presented as a reference point for engineering and operations staff for design and execution of squeeze-cementing operations. For those skilled in squeeze cementing, this information may be confirmed by others' experience and knowledge to improve success and increase understanding of squeeze cementing.
Contingency Planning Considerations for E&P Operations Near Mexican Territorial Waters
Authors: Pertuz David R. 
Published: December 2007

Abstract
In recent years there has been an increased number of E&P activities in the Western Gulf of Mexico near the international Mexico – U.S. boundary, particularly the Alaminos and Keathely Canyons. Likewise, there is interest from the Mexican government and private enterprise for conducting E&P and LNG activities in Mexican waters near U.S. territorial waters. Because of well known Gulf of Mexico loop current eddies, any significant amount of oil spilled anywhere in the Alaminos or Keathley Canyon areas or even the East Breaks and Garden Banks encounters a real potential for impacting Mexican territorial waters. E&P activities near the international boundary must take into consideration existing international agreements and lessons learned for the preparation of contingency plans.
In 1980, following the June 1979 PEMEX IXTOC I spill, the United States and Mexico signed an agreement of cooperation to draft a joint marine pollution response contingency plan. The agreement delegated to the Mexican Navy and the U.S. Coast Guard the responsibility for developing such a plan. This plan, better known as the MEXUS Plan, was completed and acknowledged by both countries in the year 2000. It addresses bilateral cooperation and procedures in response to pollution incidents that could affect the coastal waters of both countries. Oil companies operating near the international U.S. and Mexican boundaries need to be familiar with the application of the MEXUS Plan.
Since the signing of the MEXUS Plan, a series of exercises has been conducted that put to test the practical applicability of the plan. Exercise sponsors have included Unocal Corporation, Shell Exploration & Production Company, the Mexican Navy and most recently PEMEX. The lessons learned from these exercises are paramount ingredients for the development of a spill contingency plan near the international boundary. Information includes: Responsible elements, notification procedures, alternative techniques for spill response, bi-national policies, available resources, joint spill management system, customs and immigration procedures for transboundary crossing of personnel and equipment during a spill response.
Adapting International SE Management Systems for Use in the Gulf of Mexico
Authors: Day Rebecca , Teti Nathaniel J. , Deetjen Caroline J. 
Published: December 2007

Abstract
Recent growth in deepwater E&P activities in the U.S. Gulf of Mexico has drawn operators from around the world. Many of these, particularly large multinational corporations with roots outside the U.S., bring with them existing Safety and Environment (SE) Management Systems. Having been developed in different regulatory and business environments, however, these SE systems vary from U.S. requirements and practices in significant respects. Employing such non-U.S. systems in the Gulf of Mexico could pose risks and costs ranging from noncompliance to over-compliance, and could ignore important factors associated with U.S. liability regimes for which there may be no parallels elsewhere in the world.
It is imperative, therefore, that SE Management Systems be tested against and adapted fully to the U.S. environment. Even decisions to retain the over-compliant "home" systems must be made after careful consideration of the costs and consequences.
This paper will provide an overall framework for evaluating and adapting non-U.S. SE systems in the Gulf of Mexico, as well as specific areas of concern. The latter include liability regimes in the spill and personal injury arenas; reputation issues; investigating incidents; benefits and risks of "over-compliance"; use of lawyers and other consultants; and other critical areas where the U.S. offers special SE challenges. The paper also will discuss methodologies for identifying and assessing gaps, risks and costs associated with use of non-U.S. systems in the Gulf of Mexico.
Sealing Capacity of API Connections—Theoretical and Experimental Results
Authors: Badicioiu Marius , Teodoriu Catalin 
Published: December 2007

Abstract
Hydraulic fracturing has become a state of the art stimulation technique. It has been proved over the years that significant production increase can be obtained by applying the right fracturing technique. Nowadays, the most advanced techniques of geothermal energy recovery systems widely use hydraulic fracturing.
The following paper presents the experimental results of the tests carried out on four different compounds using the improved "grooved plate" method. The tests have showed a large variation of the tested thread compounds sealing capacity. Starting from the experimental results and the theoretical analysis of the API connection a useful chart was built to determine the real connection resistance, based on its initial makeup torque. The chart offers to engineers involved in the design of a fracturing process the possibility to estimate the maximum pressure that may lead to a connection leak.
Underbalanced Coiled Tubing Drilling Practices in Horizontal Short Radius Re-Entry Well Applied in Hassi Messaoud - Algeria, Case Study
Authors: Amor Bachir Ben , Ferhat Ali , Messas Rafik , Arnone Maurizio , Barakat Naiem , Schoch Fritz , Qutob Hani , Chopty James 
Published: December 2007

Abstract
The Hassi Messaoud field (Figure 1), discovered in 1956, is the largest oil field in Algeria, covering about 2000 Km2 and currently including over 1000 Wells. The field is divided aerially into 25 zones that are separated from each other by low permeability barriers, usually faults. The Cambrian Reservoir is subdivided into four lithological zones designated from base to top as R3, R2, Ra and Ri. The Ra sub reservoir shows the best petrophysical properties with a maximum thickness of 150 m in the western part of the field. The Ra is farther subdivided into five sub zones: D1, ID, D2, D3, and D4 based on reservoir properties and depositional conditions. Figure 1Hassi Messaoud field location
Well F was the 6th re-entry well in the Sonatrach Coiled Tubing – Underbalanced Drilling campaign. A total of 363 m from KOP (303 m from landing point) were successfully drilled in a continuous underbalanced condition inside D1 and ID formations. As a result, the well productivity while drilling and while production test, the reservoir characterization and rate of penetration was significantly improved, compared with offset wells, due to the positive impacts of UBD operations.
The combination of Underbalanced and Coiled Tubing Drilling technologies has been proven to be a viable solution to successfully drill horizontal re-entry wells in mature fields where the reservoir pressure is adequate to induce underbalanced conditions using single phase or multiphase drilling fluid.
The experience in this field has validated the benefits of the combination of these technologies and has been attributed to the excellent balance between drilling cost and improved productivity. For example, the drilling cost in the short radius re-entry wells drilled with coiled tubing are highly reduced due to the elimination of pipe connection procedures, the increase in rate of penetration, the prevention of conventional drilling problems such as fluid circulation loses and related differential sticking events, the increase in the bit life and reduction in time and drilled distance to reach the profitable production level.
This paper describes the technical basis for the design and implementation of the Coiled Tubing Underbalanced Drilling project in Hassi Messaoud Field and highlights the operational key factors and challenges faced during this particular and successful application in Algeria.
Data Analysis Methodology for Reservoir Management
Authors: El Ela M. Abu 
Published: December 2007

AbstractReservoir management (starting from a development plan, implementing the plan, monitoring and evaluating the performance of the reservoir) requires knowledge of the reservoir that should be gained through an integrated data acquisition and analysis program. Data analysis program requires a great deal of effort, scrutiny and innovation. The key steps are (1) plan and organize, (2) collect and analyze, and (3) integrate and store. This approach addresses a general framework of optimizing the data analysis process. This paper attempts to highlight this type of approach.The applicability of this work is confirmed by actual field case study (Shukheir Bay Field) in Offshore Shukheir Oil Company (an international joint venture company in Egypt). Such study is an original contribution to the knowledge of the data analysis process, which proved effective in clarifying the overall view of the reservoir performance in view of facilitating decision making for developmental plans.
SAGD Optimization With Air Injection
Authors: Belgrave J. D. M. , Nzekwu B. , Chhina H. S. 
Published: December 2007

Abstract
This paper discusses the recent patent application filed by EnCana Corporation on the use of air injection to improve the performance of steam assisted gravity drainage (SAGD).
EnCana's SAGD/Air Injection process employs standard SAGD well-pair infrastructure. It optimizes between the ability of steam to preheat the reservoir during SAGD and the superior (follow-up) oil displacement efficiency of in-situ combustion.
Operationally, air injection is initiated after thermal communication has been established between well-pairs with steam. One interesting feature of this operating strategy is that down-hole bulk separation of oil and gas occurs which facilitates (a) efficient monitoring and control of the combustion, (b) design of surface facilities, and (c) corrosion mitigation.
Laboratory combustion tube tests are presented that confirm the ability to initiate and sustain combustion, as well as mobilize residual oil saturation to steam, within a SAGD chamber. These experiments were initialized at oil saturations and conditions representative of those in a steam chamber. The residual oil saturations were determined from a full-hole core taken in the vicinity of a mature SAGD well-pair at Foster Creek.
Numerical simulations of post-SAGD air injection are presented that suggest the ability to displace and produce oil banks between well-pairs and that recovery factor can be increased up to 8% of the original oil-in-place over conventional SAGD.
The simulations show oil production rates and recovery factor are expected to increase with higher air injection rates. However, instantaneous air-oil ratios, which are indicative of operating costs, also increase. Thus there is an optimum continuous air injection rate that maximizes profitability. Simulations further indicate that it is possible to recycle flue gases in the injection stream without affecting oil recovery.
Remote Real Time Well Surveillance the Best Fit for Southern Part of Ghawar Area Field
Authors: Al-Amer A. A. , Dashash Alaa A. 
Published: December 2007

Abstract
Manual wellhead data collection is manpower intensive and requires significant time to collect and distribute in addition to the associated problems such as incomplete and missing data. Remote realtime well surveillance eliminated these problems by providing the data real-time and on demand. The data automation increased accuracy and efficiency in the workflow process, ensuring the best asset management to maximize the value of oil reserves. The real-time system was installed in the southern part of the Ghawar area field in which the reservoir is heterogeneous with poor rock quality and numerous faults and fractures. The fractures and faults represent possible challenges as conduits for early water breakthrough. Therefore, real-time well surveillance is essential to identify problems early on and would enable to set proactive solutions for any anticipated problems. Real-time wellhead and downhole pressure and rate data could be integrated into simulation and well performance analysis to gauge what is happening within the reservoir and help adjust and optimize production and injection strategies.
With real-time data acquisition and automation the workflow process has dramatically improved. This paper will discuss the improvement in transmitting well pressure and injection rate data and the resultant benefits. It will also highlight the real-time system description, the data flow process and Saudi Aramco's determination to be in the leading edge of this technology. This success story of using an automated real-time data system will illustrate Saudi Aramco's intention to overcome challenges by applying the best available technology.