bluuebunny/crossref_metadata_2025_split huggingface dataset:
Study and Field Application of Inorganic Composite Blocking Agent with Ultra-low Density for Water Coning Control in High Temperature and High Salinity Fractured-vuggy Carbonate Reservoir
Authors: Caili Dai , Qing You , Long He , Qin Guowei , Ping Wang , Feng Decheng , Fulin Zhao 
Published: May 2011

Abstract
Tahe oilfield in China belongs to fractured-vuggy carbonate reservoir with high temperature (100~130 celsius degree) and high salinity (two hundred thousand mg/L containing ten thousands mg/L of Ca2+ and Mg2+). After exploration for many years, the bottom water cones through fractures and vugs into production wells and then oil production declines obviously. In order to solve this problem above, a new inorganic composite blocking agent is proposed and developed in this paper. This new blocking agent is composed of superfine cement, strengthening agent, density adjusting agent, bridging agent, suspension dispersing agent, retardant and drag reducer. By adjusting the different proportions of components to make sure the density of this new blocking agent is in 1.00~1.10g/cm3 between oil (0.80~0.98g/cm3) and water (1.14g/cm3) which can build up packer existing in water-oil transition zone to control bottom water coning caused by gravity segregation resulting from density difference. Then the agent could expand sweep volume of bottom water and enhance oil recovery. This new blocking agent had been applied in one production well in Mar 2009, by Jul 2010, the accumulated oil increment is 1753.31t, the water cut decreased from 99.23% to 91.64% and the input-output ratio is up to 1:2.0. The success of field test confirmed that this new blocking agent is quite suitable for controlling bottom water coning and has a broad application prospect.
An Experimental Study of Compositional Displacements in Multi-Layered Porous Media
Authors: AlAli A. M. , AlHamdan M. R. , Cinar Y. 
Published: May 2011

Abstract
In this paper, we present a laboratory study that investigates the behaviour of compositional displacements in multi-layered porous media. A quasi two-dimensional glass bead pack was used in the experiments. The porous medium had three uniform layers with each having a different permeability because of the different glass beads. An analog two-phase three-component liquid ternary system was used in the experiments at ambient conditions to mimic a condensing gas drainage displacement under reservoir conditions. We report a total of nine experiments which include three horizontal and six vertical cross-section displacements with different injection and initial fluids. The fluids chosen represent immiscible, near miscible and first-contact miscible systems. The effluents were collected for each experiment and their compositions were measured using gas chromatography. Several snapshots of the fluid distributions in the porous medium were taken during each experiment. The experimental results show that the horizontal displacements gave a better sweep efficiency. Most of the displacements took place in the high-permeability layer with the low-permeability layer not even touched, gravity effects were favourable in the vertical cross-section displacements where the high-permeability layer was at the bottom, and the gravity reduced the swept area in the flood with the flipped vertical cross-section model. The measured compositional data indicates differences in the compositional paths for different displacements.
Effective Well Placement and Trajectory Planning Approach through Collaboration Environment Tools
Authors: Al-Baqawi Ahmed M. , Al-Naim Hamad A. , Araque Telemac Arcides J. , Habbtar Ali H. , Ismail Menhal A. , Al-Kanan Adnan A. , Al-Utaibi Abdullah A. 
Published: May 2011

Abstract
Well placement and trajectory planning is a critical and challenging task in any Oil & gas field development plan. This has always been a task that requires a strong team effort to ensure the best predictions and estimations are performed to penetrate the desired reservoir development zones and achieve the expected production rates. Numerous iterations with a high level of interaction between Reservoir Management, Reservoir Simulation, Reservoir characterization, Geology and Geophysics are expected when planning a new well or a difficult sidetrack.
Each member of the well planning team has his/her own environment along with dedicated standalone software tools. Today, with the introduction of the Intelligent Field center to provide the collaboration environment for the involved expertise along with the proper tool to offer a strong integration of different data sources in a single software environment that allows a team of field geologist, geophysicist, reservoir and simulation engineers to evaluate the best prospects available in planning any new drilling opportunity, furthermore the team is able to choose the best well azimuth and inclination based on reservoir properties and performance.
This paper discusses a newly integrated well planning process utilizing a collaboration environment to review seismic, well log cross sections, historical production and simulation predictions enabling the well planning team to place their gas wells using a reservoir 3D viewer, incorporating the reservoir simulation model, and run various cases and sensitivities. In This paper, full examples illustrate how effective software integration can optimize the time required to plan a new well without overlooking any important aspect. In addition, the paper discusses the lessons learned from this experience and how this approach changes the mechanism of an integrated well planning team working together.
Smart Combination of Technology Tools Resulted in Successful Rigless Stimulation on a Tri-Lateral Well, Case Study
Authors: Al-Zain Ahmed , Al-Gamber Abdulwafi , Said Rifat 
Published: May 2011

Abstract
Drilling horizontal wells has become the more commonplace in many Saudi Aramco fields. Recent advances in drilling and completion practices enable the drilling of more complex wells with various types and shapes such as extended reach wells, bi-laterals and multi-laterals for providing maximum reservoir contact. These complex wells impose great challenges with respect to rigless well interventions. One of the initial well interventions, which follow drilling completion, is acid stimulation to remove formation damage. The challenges raised because of well complexity include accessing the laterals, reaching the end of each lateral and properly distributing treatment fluids over entire horizontal sections.
Effective rigless interventions in these challenging wells have limitations and technologies are still evolving. Deployment of tools and fluids downhole is no more possible through conventional coiled tubing applications. New techniques have been developed to assist coiled tubing (CT) to access laterals and extend their reach. In addition, recent advancement of CT bottom-hole assembly (BHA) allows combining services of more than one function such as deploying tools and fluids and at the same time acquiring vital downhole data.
The fiber optic enabled CT (FOCT) provides combined services of data acquiring on real time and running crucial CT technology tools. By the virtue of the optical fiber, distributed measurements could be made available to obtain temperature profiles. The temperature surveys allow evaluating flow distribution through temperature responses; hence, optimizing acid stimulation. FOCT with a flow-through BHA coupled with smart combination of technology tools such as a multi-lateral tool (MLT) and a mechanical drag reducer tool provides integrated services.
This paper highlights the first ever worldwide combination of technology tools via FOCT for acquiring downhole data on real time and technology tools for accessing and extending the reach of the CT for stimulating a tri-lateral oil producer in a major carbonate reservoir in Saudi Arabia. This combination has resulted in successful acid stimulation of all three laterals. The paper also discusses in detail the application of distributed temperatures for placing treatment fluids and experience gained.
An Accurate Prediction of CO2 Minimum Miscibility Pressure (MMP) Using Alternating Conditional Expectation Algorithm (ACE)
Authors: Alomair Osamah , Malallah Adel , Elsharkawy Adel , Iqbal Maqsood 
Published: May 2011

Abstract
Miscible gas injection nowadays becomes an imperative enhanced oil recovery (EOR) approach for increasing oil recovery. Due to the massive cost associated with this approach a high degree of accuracy is required for predicting the outcome of the process. Such accuracy includes, the preliminary screening parameters for gas miscible displacement; the "minimum miscibility pressure" (MMP) and the availability of the gas. All conventional and stat-of-the-art MMP measurement methods are either time consuming or decidedly cost demanding. Therefore, in order to address the immediate industry demands a nonparametric approach (ACE) is employed in this study to estimate an important parameter MMP. ACE algorithm correlates optimal transforms of a set of predictors with an optimal response transform. Finally, the proposed model has produced a maximum linear effect between these transformed variables. More than 100 MMP data points are considered both from the relevant published literature and experimental work. The test data points also MMP measurements that are experimentally obtained for Kuwaiti crude Oil. The proposed model is validated using detailed statistical analysis and it reveals that the results are more reliable than the existing correlations for pure CO2 injection to enhance oil recovery. In addition to its accuracy, the ACE approach is more powerful, quick and can handle a huge data.
Exceeding Well Life Design in Mature Field Using Well Integrity Management System
Authors: Calosa Weka Janitra , Rahman Hibatur , Dewanto Christianto Widi 
Published: May 2011

Abstract
High oil prices, new technology to increase oil recovery and government incentives can allow economic oil production to exceed the well design life. However, well life extension may result in more frequent critical failures involving leakages to the environment and structural safety issues during well service jobs.
Well Integrity management is a way to keep oil flowing from mature fields with extended wells lives with an environment friendly safe operation. This paper discusses the well integrity system implementation in a field in the Malacca Straits PSC, which contains mature oil fields with more than 30 years of oil and gas production.
This field has well integrity problem including leaking wellheads, severe corrosion of well components, failure of cement bonding, and land subsidence.
The well integrity management system assesses each well, evaluates the well operation in term of safety, and provides timely recommendations on remedial actions to keep the well producing.
The system also carries out quantitative data analysis and provides feedback to the operator about the condition of individual wells and overviews of whole field integrity.
The benefit is longer economic production with safe operational practices. This system was implemented in the MSAC-14 well, and the conclusion was the integrity of the MSAC-14 well was acceptable.
NanoEmulsion for Non-Aqueous Mud Removal in Wellbore
Authors: See Chun Hwa , Saphanuchart Wasan , Nadarajan Sritharan , Lim Chia Ni 
Published: May 2011

Abstract
Efficient mud removal, filter cake removal and formation clean-up are critically required for well cementing, production and injection wells drilled with non-aqueous mud. Conventional surfactant clean-up system requires a turbulent flow and large volume to solubilize residue efficiently. Unsuitable surfactant system may cause emulsion blockage and oil-contamination in the completion brine, which consequently leads to a reduction in oil production rate. A new potential method to overcome these problems with higher efficiency to remove non-aqueous mud and filter cake is NanoEmulsion technology. This technology able to reduce the oil-water interfacial tension (IFT) down to &lt; 0.001 mN/m, solubilize much larger amount of oily hydrocarbons without any mechanical stirring needed. This paper elucidates the potential of NanoEmulsion technology in removing non-aqueous based mud and filter cake during wellbore cleaning through laboratory scale set-up at ambient and HTHP conditions. The impact of temperature, pressure, mono- and divalent electrolytes, bridging agent such as calcium carbonate, acidity and polymers (Xanthan Gum and HEC) have been studied. It was found that the NanoEmulsion is effective in removing non-aqueous mud in all studied conditions at tested duration of &lt; 10 minutes. The cleaning mechanism proposed are: (1) instantaneously reducing interfacial tension between oil-water and oil-solid surfaces, (2) emulsify and solubilized oil content, (3) facilitate wettability and allowing water molecules to penetrate in-between oil and solids surfaces, causing the oil to spontaneously repel from the hydrophilic solid surfaces, and (4) separation of oil from water and solids. This enables the recycle of the oil content which is free from solids. NanoEmulsion technology can be incorporate with acid to simultaneously dissolve calcium carbonate bridging agent and solubilize the oil in the filter cake. In addition, it is free from benzene, toluene and xylene (BTX), synthesis from bio-degradable natural sources, non-toxic, easy to handle, and 100% biodegradable.
Multizone Well Testing with Downhole Tools in Extreme Sour-Gas Conditions
Authors: Hollaender Florian , Salsman Alan , Neyaei Fardin Ali , Singleton Richard , Al Badi Fuad , Rigatos Efstathios , Ali Ashraf , Anwar Mohamed 
Published: May 2011

Abstract
A recently drilled appraisal well in a multilayered carbonate reservoir was successfully tested using downhole tools in very hostile downhole conditions. While the reservoir pressure and temperature were not excessive, the combined concentrations of hydrogen sulfide (H2S) and carbon dioxide (CO2) were well above anything that has been tested in the past with similar tools. Four different zones were tested individually using a fit-for-purpose test design, which allowed for testing two zones per trip. The services included downhole tools for shut-in and well-control purposes, bottomhole samplers, memory gauges, through-tubing perforating and coiled-tubing intervention through the test string to acid stimulate, N2 lift, and set cement plugs between zones.
The use of the downhole test string provided the means to carry out a complete well test with downhole shut-in and sampling controlled from the surface. The operational flexibility offered by the string allowed for all operations to be successfully performed even with lengthy exposures of the tools to sour fluids. This appraisal well is one of a series of wells drilled in this area but the first one in which very extensive data acquisition has been acquired thanks to a detailed well-test procedure and job planning.
This test required a significant amount of prejob planning, in addition to attention to detail in the execution and onsite preparation and maintenance. Our paper describes the test requirements, the prejob planning, and the execution that led to the successful completion of this well test in very hostile conditions, the first of its kind in this part of the world.
Altering Sweep Profiles during Waterflooding Using Near-Wellbore and Deep Reservoir Controls
Authors: East Loyd E. , Sierra Leopoldo , Soliman Mohamed Y. 
Published: May 2011

Abstract
Water, CO2, and steam flooding in oil wells are common today as many of the premium reservoirs are becoming significantly more difficult to efficiently produce. Much of the technology for optimizing the recovery in these assets revolves around well placement and production controls. When early flood-front breakthrough occurs, the options for improved asset economics are generally limited to near-wellbore controls to minimize the costs of producing, separating, and disposal of nonhydrocarbon production. Often, these controls have short-term effectiveness, and intervals or wells are prematurely abandoned. Altering flood fronts deep in the reservoir will offer much greater effect and longer-lasting control of nonhydrocarbon production. Successful alteration of the sweep pattern deep in the reservoir yields better sweep efficiency, lower operating costs and higher ultimate recovery.
This paper explores the benefits of well completions that incorporate a combination of near-wellbore and deep reservoir controls to modify the fluid-flow pattern when production coincides with an active water flood. By using numerical simulation of various completion methodologies with and without these controls, the benefits will become apparent. Optimization of these controls for a given completion will be illustrated for a single producer horizontal with vertical injector and for a producer pair of horizontals with a horizontal injector.
A new Method to Determine Marble Provenance with XRD Accessory Mineralogy
Authors: Lynn Jack D. 
Published: May 2011

Abstract
Calcium carbonate, used as a "sizing" material to aid in fluid loss control during drilling/completion operations, is supplied to Aramco in a number of different pre-ground diameters (e.g., Chips, coarse, medium and fine), by a number of vendor/suppliers. In order to provide "abrasion resistance" (in itself, a nebulous terminology), the drilling carbonate is specified to be supplied as "marble", i.e., metamorphic calcium and dolomitic carbonates. The problem to drilling engineers and fluid specialists has been certification of a supplied product as an abrasion resistant "marble" or simply a low strength, sedimentary limestone/dolomite. Determination of the source or "provenance" of a sample is critical to obtaining a quality product from vendors.
This specification as "marble" has inherent QA/QC problems in that standard XRD cannot differentiate metamorphic carbonate from sedimentary limestone/dolomite. Previous methods relied on petrographic examination (polarizing light microscopy) of thin sections of sufficiently large samples, impossible with finely ground material.
A new method of evaluating drilling carbonate samples to determine their mineralogical provenance has been developed, that can be used on solids of any size, even in samples of solids isolated from the drilling mud during drilling operations. The method uses XRD/XRF data generated on acid insoluble residuals of the drilling solids material. Paragenetic origin can be determined based on the accessory mineral assemblage, which is well defined in the literature. In addition, a new compositional ternary diagram has been introduced, termed the M-C-A (MgO-CaO-AL2O3).
Based on the new technique, 18 carbonate drilling samples were first evaluated for acid solubility, and the residual material (insoluble) used for assessment of mineralogical provenance. The new method has the following characteristics: The new method is a robust QA method for rapid determination of marble provenance.The new method is found to be able to differentiate mineralogical provenance in carbonate samplesThe new method can quickly screen samples for potential formation damage issues.The samples can come from a fresh batch of carbonate before delivery to the field sites, or the method can be applied forensically by taking samples from the mud pits and shakers for evaluation.Given a sufficient data base, the method will be able to identify IK and OOK quarry sources of metamorphic marbles supplied by vendorsThe method can be used for rapid QA on new IK sources of metamorphic marbleThe new method can be easily incorporated into a new standard procedure for drilling marble QA, which should include ○Solubility in 20 weight percent HCl○Mineralogy by XRD/XRF (bulk and accessory minerals, separately)○Particle size distribution○Crush resistance (e.g., particle attrition tests)
The new method will provide a quick and effective method to certify drilling carbonate as marble, thus having the accepted abrasion resistance.
The Importance of Production Logging Sequence When Designing Inflow Control Completions
Authors: Lauritzen J. Eric , Al-Julaih Ali H. , Al-Momin Ali , Shahreyar Noman , Young Dustin 
Published: May 2011

Abstract
Production logging at multiple rates is used to correlate passive inflow device (ICD) completion designs to actual downhole flow rates for performance validation and design improvement. Accurate steady-state multi-rate production logging is quantitative proof of design for completion evaluation. When low rates are recorded first in wells that have not been fully unloaded, and then are followed up with high rate passes, the PI per compartment values may change due to unloading. When this occurs, the simulations will not match both rate curves because the production profile has changed in the time it took to log the two rates. Unloading at high rates may result in rapid wellbore cleanup, and the production-profile changes that are due to the cleanup rates will be evident. When this occurs, the utility of the lower rate PLT dataset is greatly diminished. This paper discusses the importance of performing production logging tests for the evaluation of flow contribution in ICD completions. Sandstone and carbonate case studies are presented that will illustrate the benefits of using a properly sequenced logging strategy for ICD completion performance evaluation. Multi-rate and high-to-low rate-production testing is highlighted, since it has resulted in improved well clean up and productivity. Multi-rate production logging also helped to differentiate between non-productive and the damaged zone sections along the horizontal. This comparison verifies the value gained for operators when an appropriate production-logging test design is put into practice.
Use of the Memory Concept to Investigate the Temperature Profile during a Thermal EOR Process
Authors: Hossain M. Enamul , Abu-Khamsin Sidqi A. , Al-Helali Abdul-Aziz 
Published: May 2011

Abstract
Accurate prediction of the temperature profile within a reservoir undergoing a thermal recovery process is a key factor in process design, production forecasting and reservoir management. Such profile is governed by the heat transfer between the rock matrix and flowing fluids, which is highly dependent on the thermal and rheological properties of the rock and fluids involved. In this work, the role of temperature-dependent rock and fluid properties in the development of the temperature profile during the thermal process was investigated employing the continuous time function as "memory." Mathematical models were developed in terms of a group of heat transfer dimensionless numbers that correlate the varying rock and fluid properties. New heat transfer dimensionless numbers are proposed which can be characterized by rock and fluid properties. The model equations were then solved numerically through MATLAB programming to produce temperature profiles for a typical steam flood where the rock and fluid temperatures are assumed unequal throughout the reservoir, i.e. the rock does not attains the fluid temperature instantaneously. Results reveal the development of a temperature profile within the growing condensed water zone that is flowing ahead of the steam zone. The rock and fluid temperature profiles were found sensitive to the rheological properties, time and fluid velocity. The proposed model would be useful for better prediction of reservoir performance.