bluuebunny/crossref_metadata_2025_split huggingface dataset:
Effective Permeability vs. Drainage Radius, Correlation for the Turbidites Oil Reservoirs—Chicontepec Paleochannel
Authors: Gachuz-Muro Heron 
Published: March 2009

Abstract
Chicontepec is associated to a submarine fan system deposited under complex tectono-stratigraphic conditions. Typically, between 8 and 16 major reservoirs are present. These set of reservoirs is composed of channel complexes that are flanked by, and rest on, lobe sandstones that grade into distal fan and basin floor deposits, resulting in high heterogeneity. All the reservoirs have permeabilities of 0.1 to 10 mD and porosities of 5–15 %. Primary recovery by solution gas drive is less than 5 %. The oil density varies from 18 to 45 °API depending on his structural position.
An aggressive number of well tests were conducted to characterize the fields in Chicontepec. Theses include build up, fall off, drawdown and step rate tests. In recent years, the tests were analyzed to identify well and reservoir factors affecting productivity as well as to determine the effectiveness of well stimulation by fracturing. The typical models used to adjust the information were both vertical fracture and radial homogeneous models. The effective permeability, as determined for these tests and/or advanced decline analysis, ranges from 0.1 to 15 mD. The results seem to indicate that the partial closing of the fractures is caused during the early exploitation. Further analyses suggest that the reservoir rock quality (facies model) along the linear and/or bilinear flow periods having a link with good production rates.
This paper presents a relationship found between the effective permeability and the drainage radius. This relationship could be applied to turbidites oil reservoirs with low permeability and low porosity. In order to avoid the interference problems and to optimize new wells, we propose an optimal drainage radius obtained of well test data, pressure-production history and composition fluids.
Improved Waste Injection Monitoring and Modified Operational Procedures: The Keys to Prolong Well Storage Capacity
Authors: Ovalle A. , Ronderos J. , Benelkadi S. , Gumarov S. , Simmons S. 
Published: March 2009

Abstract
Waste generated during exploration, development, and production of oil and gas fields are required to be disposed in a responsible and environmentally friendly manner. Over the years, environmental regulations governing the disposal of such waste have tightened and each day regulatory agencies are demanding more stringent policies, especially for remote and environmentally sensitive areas. Waste Injection (WI) has been proven over the past decade to be the safest and most efficient technology for final disposal of waste materials such as produced water, drill cuttings, spent drilling and completion fluids, scale waste, NORM, produced sand, production and well cleanup waste. This cost-effective technology complies with the strict environmental guidelines, such as the ones governing zero-discharge environments. More regulatory agencies are gradually recognizing WI as a robust solution to safe and assured final disposal of waste generated in upstream and downstream sectors of the oil industry.
WI has evolved from a simple pumping operation, with lack of sub-surface understanding, to an assured process that has integrated the knowledge from all areas of the operation: engineering design, equipment and operational parameters, monitoring, and quality control-quality assurance. This continuous assessment guarantees a cyclic process that identifies potential risks at early stages, and allows proper management and mitigation to prolong the life and integrity of the operation.
This paper presents the unique and technically challenging injection monitoring and pressure interpretation experience attained in different WI projects worldwide, where the in-depth interpretation of fracture behavior helped as a risk-prevention tool with mitigation options applied to operational parameter well specifics.
The continuous monitoring of injection data and parameters assists in developing a well history and a prediction mechanism for well storage capacity, extending the life of the injector and maximizing efficiency for the development of the field.
Enhancing Decision Making in Critical Drilling Operations
Authors: Shokouhi Samad Valipour , Skalle Pål 
Published: March 2009

Abstract
Many critical tasks in oil operations require cognitive skills for safe and efficient drilling. Oil well drilling is a complex process which frequently is leading to operational problems. One problem is wellbore cleaning. If the root cause of the problem was known, the treatment of the problem could be made more focused and efficient. However, to determine the root cause is difficult in this coupled process. One solution to this challenge is to apply knowledge intensive case based reasoning (KiCBR) methodology. KiCBR is a recent approach to problem solving and decision making where a new problem is solved by finding a set of similar previously solved problems, called cases, and reusing them in the new problem situation.
This approach consists of two major parts: hierarchy of the concepts with different relation strength and case based reasoning. Concepts are abstracted to symbolic entities. Through the selected fields, data (real time logs, end of well plan and daily drilling reports, etc) are utilized to provide case data base. In this study, three main root causes were chosen; solids accumulation, problematic formation leading to future well cleaning and problematic formation causing well cleaning problems. This paper presents how to determine the root causes for poor hole cleaning episodes by means of the CBR (Case-Based Reasoning).
All the involved parameters in each case were stored in the data base. Whenever an unexpected episode is encountered, highly similar case from the data base will come out for decision making. Furthermore, each case has specific and general lessons for those who are in charge of the operations. The match results were good enough but it needs to be improved through indicators that will reveal main cause more precisely.
Two-Zone Commingled Production using Intelligent Well Completion Coupled with ESP through a Hydraulic Disconnect Tool
Authors: Ansah Joe , Quaimi Bander I. , Shehab Mahdi A. , Al-Ajmi Fahad A. , Bani Fahad A. , Jacob Suresh 
Published: March 2009

Abstract
A dual-reservoir completion using Intelligent Well system together with an electrical submersible pump (ESP) in a high-rate well was recently deployed in one of the large carbonate fields in Saudi Arabia. The well was equipped with ESP to provide artificial lift to pump the oil to a centralized processing facility that is far a way from the well through a 2-zone "Smart" well completion, which remotely controls fluid inflow from each of the two laterals. This completion enables commingled production from two reservoirs while balancing flow contribution from each reservoir and avoiding cross-flow from one reservoir into the other.
Commingled production from stacked reservoirs in the same field, or a single reservoir with multiple pay intervals, has many benefits during the development of a field – higher production rates per well, cost savings from reduction in the total number of development wells, flexibility in locating surface facilities as a result of minimal footprint, etc., Wide variation in reservoir properties, coupled with existence of natural fractures within an active waterflood environment in this case, prompted adoption of Intelligent Well technology to control fluid withdrawal and enhance waterflood front conformance. Additionally, there was a need to use proven conventional ESP system to lift the expected high production rates from the two prolific reservoirs.
The new completion uses a re-designed downhole hydraulic disconnect tool with an integral anchor assembly, instead of other systems that have been used in the industry in the past, to connect the upper completion incorporating the ESP system with the lower completion that incorporates the Intelligent Well completion. Thus, ESP workover can be performed without the need to retrieve the Intelligent Well completion. This integrated system has enabled the two producing reservoirs to be commingled successfully and has provided the flexibility to control inflow from each reservoir in the future as the flow regimes change.
This paper describes the equipment selection process, completion equipment, planning and deployment procedures of the Intelligent Well completion. Economic drivers for this robust completion as well as the reservoir management implications of successful deployment in this test case well and future expansion across the entire field are also discussed.
FDP-Revisions: Keeping Your FDP's Green in a Fit-For-Purpose Manner
Authors: Garimella Sai , Kloosterman Henk Jaap , Horstmann Dirk , Gheithy Ali 
Published: March 2009

Abstract
Petroleum Development Oman (PDO) is operating many technically complex and mature onshore oil fields in the Sultanate of Oman. Recently PDO has established a ring-fenced Study Centre to carry out Integrated Field Studies to maintain up-to-date Field Development Plans (FDP's). Generation of a robust updated FDP typically takes up to 18 months, and takes into account full subsurface uncertainty and development options analysis in order to arrive at the optimum development. When executing these FDPs, new subsurface data comes in, which often generates new insights in the field that need to be incorporated. This does not require always a full new FDP-study, but a focused revision of the existing FDP. A so-called ‘Hit-Squad’ team was established to deliver these quick & fit-for-purpose FDP-revisions.
In this paper, a case study is presented related to a mature clastic oil field in the Sultanate of Oman. The latest FDP, generated in 2004, proposed a peripheral waterflood, however, the expected pressure support was not observed in the crestal part of the field. This created an exposure in terms of expected oil recovery and jeopardised the remainder of the FDP-implementation. This paper describes how the ‘Hit Squad’ attacked the problem and delivered a fit-for-purpose FDP-revision to bring the remainder of the development back on track.
This involved upfront understanding of the key issues. It was recognised early on in the project that the static model definition was not the main cause of the waterflood underperformance. The core of the problem was the poorer than expected injectivity of the 2007 flank injectors, which in combination with the adverse mobility ratio and the relatively large injector/producer spacing caused the poor waterflood performance. In addition, existing infield injectors were rate constrained to avoid excessive induced fracturing and short circuiting of water. Therefore, the focus immediately was directed to the relevant work activities to screen and optimise an infill pattern flood.
The team produced within five months a revised development plan, now proceeding with an optimised pattern waterflood, with 40 well locations identified and picked, resulting in no loss of recovery or delay to the development. The first well was drilled within 2 months of study completion and came in as predicted (Depth, SHC, Pres, Qinj). The key success factors were the ring-fenced nature of the integrated team, as well as the seamless cooperation between Asset and Hit Squad Teams. The concept of the Hit Squad is generic and should find wider application in the industry.
Increasing Production and Injection in Multilateral Horizontal Wells in Naturally Fractured Carbonate Reservoirs by Rigless Intervention—A Case Study, Offshore, Qatar
Authors: Lisigurski O. , Ferdiana W. , Haro C. , Maili E. 
Published: March 2009

Abstract
Due to the complexity and cost of stimulating horizontal multilateral wells in an offshore environment, all aspects of this project type must be considered prior to project implementation. Utilizing all technical disciplines to understand the reservoir characteristics and select intervention candidates greatly influences the chance of success for any project.
During 2006–2008, 39 wells (19 producers, 17 water injectors and 3 gas injectors) were stimulated in the Shuaiba reservoir in Idd El Shargi North Dome Field, offshore Qatar, resulting in production increases as high as 50% and injection increases as high as 100% in some wells. The wells were stimulated by rigless coiled tubing. A new tool that allows coiled tubing to enter each lateral in multilateral wells was used for these projects. This successful acid stimulation workover program utilized the fundamentals of engineering, geology, geophysics, and petrophysics and applied them with field operations. The screening methods developed led to further workover activity and new drilling development with anticipated reserve and production increases.
Forecasting OPEC Crude Oil Supply
Authors: Al-Bisharah Mohammed , Al-Fattah Saud , Nashawi Ibrahim Sami , Malallah Adel 
Published: March 2009

Abstract
No one can underestimate the importance of crude oil in the modern world today. It is considered the key foundation of the world's first trillion-dollar industry and the principal item in the balance of payments and exchanges between nations. To truly appreciate the significance of this precious commodity, just imagine the day when all of the world's transportation systems and factories cease to function when the world has consumed its last drop of oil. This brings us to the main and crucial question: How long will oil last?
Crude oil is the lifeblood of the 12 member-nations of the Organization of Petroleum Exporting Countries (OPEC), which produces 40% of the world's oil supply and holds three-quarters of the proven reserves. Reaching oil production peak can be alarming to OPEC members, where oil revenue is the main feeding stream of the gross national product (GNP).
Many researchers, in the past decades, tried to find an answer to this crucial and critical question. Unfortunately, crude oil supply forecasting is a challenging endeavor.
This paper presents our forecast for the OPEC countries supply of crude oil to years beyond 2050. We applied the "multi-cyclic Hubbert" approach that accurately models the oil-production history of OPEC countries, which are virtually most of the world's crude oil supplier.
The analysis indicates that the OPEC ultimate oil recovery is about 1.137 trillion barrels. Of this amount, about 0.9117 trillion barrels remain to be produced by the end of 2080, where the peak is expected to be in 2025 at the production rate of 90 million barrels per day. OPEC has 77% of the world's remaining reserves. Furthermore, most OPEC countries will peak between 2020 and 2030, and they will remain the world main supplier of crude oil for the next 200 years.
Investigating the Mechanism of Thermally Induced Wettability Alteration
Authors: Roosta A. , Escrochi M. , Varzandeh F. , Khatibi J. , Ayatollahi Sh. , Schafiee M. 
Published: March 2009

Abstract
Wettability is known as the relative tendency of a fluid to wet a solid surface in the presence of another fluid that coexists in a system. Oil recovery efficiency of an oil-wet rock, mostly fractured carbonate formations, could be improved by the spontaneous imbibition of water if the rock wettability is changed. In this study, contact angle measurement was used to investigate the effects of aging time in crude oil as well as those of steam exposure on the wettability of calcite, mica, quartz, and glass surfaces.
The effects of rinsing the aged surfaces with different solvents on wettability were also studied to check the accuracy of the method and the contact angle measurements process utilized in this work. Different results of wettability alteration were observed when the mineral surfaces aged in the crude oil were exposed to steam. Quartz, calcite, and glass surfaces regained their original water wetness, while mica surfaces showed a tendency toward increased oil wet behavior. Among the tested minerals, calcite surfaces yielded the least wettability alteration when exposed to steam. Glass micro-models were also used to investigate the effect of steam and hot water injection on their wettability. Results of fluid distribution and residual oil saturation in micro-models showed that the wettability changed toward water-wet during steam and hot water injection.
Innovative Solution for Drilling Pre-Khuff Formations in Saudi Arabia Utilizing Turbodrill and Impregnated Bits
Authors: Carrillo Gabriel , Farid Usman , Albrecht Michael , Cook Perry , Feroze Nouman , Nevlud Kenneth 
Published: March 2009

Abstract
The abrasive Pre-Khuff sandstones combined with high downhole temperatures and the propensity for BHA and bit sticking present a uniquely hostile drilling environment. These limit run durations and the ability to optimize ROP with the use of conventional rotary assemblies, PDMs/conventional turbodrills and/or rotary steerable systems. Catastrophic damage or loss of drill strings, poor hole quality and logging problems are common even with the advancements in PDC bit technologies.
Of the systems listed above, historically, turbodrilling systems have best addressed the high temperatures and the abrasive nature of the Pre-Khuff formations and held the potential for drilling economics optimization but have been unsuccessful in addressing bit sticking challenges. The resultant development of best practices produced only marginal results because they require surface intervention and thus did not fully address sticking problems (in particular bit sticking).
The engineering challenge was to develop a downhole device that automatically engages and imparts sufficient drill string torque to maintain bit rotation. The turbodrill device disengages when conditions return to normal and returns the operation to high productivity drilling without surface intervention. The turbodrill device coupled with advancements in BHA design, stabilizer and jar placement along with formation characterization and drill bit technology, is the solution to bit sticking incidents.
Presented with this advancement in turbodrilling technology, the Operator/Service Company team has completed trials using this technology and presents data that supports the use and benefits of anti-sticking technologies. With this success, the team has regained focus on drilling optimization and reset the goal for single run-casing point to casing point.
Petroleum Development Oman's Experience in Using Near-Infra Red Absorption Based Water Cut Meters for Well Testing and Production Monitoring
Authors: Al-Hanashi Khalil , Al-Sibani Salim , Lievois John 
Published: March 2009

Abstract
Continuous and accurate water cut measurement is a challenging aspect in well testing and production monitoring in Petroleum Development Oman LLC (PDO). As PDO's fields are ageing and water cut is increasing, the need for more accurate water cut measurement is becoming essential. A field trial of different water cut measurement technologies was conducted in October 2004. As a result, near-infra red absorption measurement principle was found to be a promising technology. Therefore, the first near-infrared based water cut meter was first introduced in PDO in 2005
Today more than 300 units of the above mentioned water cut meter are installed in PDO. Different applications and installations of the same water cut meter across PDO are discussed in this paper. These applications include well testing, gathering and production stations production monitoring and monitoring water in oil from test separator oil leg outlet. This paper highlights the pros and cons of each of the applications where the near-infra red absorption based water cut meter is used in PDO operations. To get more accurate well test in high water cut wells, PDO deployed the same water cut meters together with Coriolis flow meters for well testing in the highest oil producer field in PDO, with high water cut (above 90% on average). This paper presents PDO's experience as an end user.
Although using near-infra red absorption based water cut meters is relatively new in the oil and gas industry, it shows a promising potential for better water cut measurement accuracy. Caution must be given to the surrounding conditions that can affect the performance of the meter, specifically the homogeneity of the flow. Configuration and proper setting of the water cut meter is an essential first step for accurate water cut measurement
Sabiriyah Upper Burgan Geological Model and Reservoir Characterization
Authors: Al-Aziz Sabry A. , Al-Rowyeh Anwar , AL-Enezi Talal , Chetri H. B. , AL-Anzi Ealian 
Published: March 2009

Abstract
Sabiriyah field is located on North Kuwait area and was discovered on 1956 and producing from multi reservoirs. The upper Burgan is a multi billion bbl reservoir in NK, with very high degree of reservoir heterogeneity and extremely complex due to combination of discontinuous channel and shore face sandstone.
The objective is to make a detailed stratighraphic correlation, build 3D static model to evaluate reservoir units, maps individual sand bodes within each unit, management and development the reservoir. Also would help on a major program of water injection plan.
The SAUB reservoir 150 feet thick (early late Albian age) is classified into 6 depositional facies, 7 main reservoir unit and 20 flow unit based on integrated all data available via open hole logs, computed logs, seismic structure depth map of top reservoir, sedimentology studies, RFT and cores data. The correlation scheme has been created based on the identical of field wide correlatable surfaces which were picked from cored wells and interpreted easily on well logs and applied thru the entire field. Twenty one markers have been traced a cross the field, gross maps honoring the depositional trends have been prepared and used with top reservoir structure depth to generate the structure depth for each marker. Net sand maps were generated & carefully edited to reflect the conceptual model and used as an areal guide for deterministic distribution of property models as well as facies model. The high resolution model is achieved by generating 3 D faulted grid and integrating all the components such as all the structures, deterministic maps and petrophysical results in to one geocellular model.
The SAUB model presents a very successful case for the integration of different disciplines and considered a milestone for the recent activities in such heterogeneity reservoir in Kuwait.