bluuebunny/crossref_metadata_2025_split huggingface dataset:
Waterfracs - Results from 50 Cotton Valley Wells
Authors: Mayerhofer Michael J. , Meehan D. Nathan 
Published: December 2007

Abstract
In previous publications we showed that several fracture treatments using treated water and very low proppant concentrations (waterfracs) were very successful in the East Texas Cotton Valley sandstone. This paper expands on the production examples with a more comprehensive set of production comparisons of wells completed with standard fracture treatments and waterfracs since 1995. The data sets are from three different Cotton Valley fields and include approximately 50 waterfrac treatments.
P. 489
Application of The First Multiphase Flowmeter In The Gulf of Mexico
Authors: Stokes Edward G. , Perry Dennis T. , Mitchell Marshall H. , Halvorsen Martin 
Published: December 2007

Abstract
This paper focuses on Conoco's recent installation and production measurement performance testing of the first Multiphase flow meter installed in the Gulf of Mexico. It summarizes the observations and conclusions made during the field evaluation tests. The paper also discusses the technical JIP development of the Fluenta model MPFM 1900VI Multiphase flowmeter that was used in these tests. Finally, the paper compares the meter's performance during the final development and verification testing program which took place at Conoco's Multiphase flow test loop prior to the field testing program.
P. 361
Wellsite Wet Gas Measurement System in Saudi Arabia
Authors: Al-Taweel Ahmed B. , Barlow Steve G. , Hussain Shahid 
Published: December 2007

Abstract
This paper describes an automated and compact wet gasmetering system that was installed and tested successfully at Saudi Aramco. The paper also describes the technology for determining individual liquid rates in production streams using the tracer dilution technique and its application in Saudi Aramco.
The system operates at a wellsite and provides continuous online measurements of liquid and gas rates for a gas well. The wet gas metering system provides reliable measurement of well producing rates and, in turn, better control of field operations and more accurate production allocation.
As a part of the wet gas metering system; the tracer dilution technology is capable of determining the magnitude of individual liquid flow rates at the wellhead, without separating the produced fluid. For a wet gas producer, this technique combined with a venturi meter can provide a three-phase measuring system, a complete alternative to a conventional welltest separator facility.
The wet gas metering system is based on the venturi principle to measure gas and condensate. The venturi principle is a proven technique which has been commercially used in oil and gas metering for years. Venturi meters have the advantages of high pressure and temperature ratings, low pressure loss, minimal wear and well established correction factors to account for entrained liquids. The rate of the entrained liquids will be measured by the tracer dilution technique.
The tracer dilution technique involves the injection of fluorescent tracers, one for hydrocarbon liquid and one for water, into the flowline and the subsequent collection of a sample at a suitable distance downstream of the injection point. The fluorescent intensity ratio of injected tracer to collected sample is used to determine the oil/condensate and water flow rates. The tracer dilution technique is viewed as a feasible and economical option to measure liquid rates in wet gas flow streams. The tracer dilution equipment is self-contained, compact, and portable.
Saudi Aramco has field-tested tracer technology in conjunction with wellsite venturi meters, as an alternative to centralized conventional test separators. Field application showed water and condensate measurement to be within +/- 10% and a gas rate measurement to be generally less than 5% of the conventional measurement technique.
P. 481
3D High-Resolution Reservoir Monitoring From Crosswell Seismic Data
Authors: Washbourne John , Bube Kenneth 
Published: December 2007

Abstract
Decreasing costs in the acquisition of high-resolution cross well seismic data have stimulated the development of new 3D imaging techniques that can provide accurate and cost-effective monitoring of reservoirs on scales of a few feet. We introduce an integrated 3D modeling approach that can simultaneously process data acquired from multiple crosswell profiles, can handle data acquired from highly deviated wells in areas of complex structure, and that assures 3D model continuity without interpolation. We have tested our modeling approach with fully 3D datasets and concluded that cross well seismic in three dimensions is now a reality.
P. 547
Intelligent System for Monitoring and Control of Downhole Oil Water Separation Applications
Authors: Tubel Paulo , Herbert Roger P. 
Published: December 2007

Abstract
This paper describes an intelligent system used to monitor and control the separation of oil from water downhole with simultaneous re-injection of the water into a zone accessible from the same wellbore. The paper outlines the individual technologies that make up the system, describes how the technologies are assembled in the wellbore, and indicates what requirements the system has of the wellbore. The paper provides a description of an intelligent system that significantly reduces water produced from a borehole while potentially increasing oil production. The paper describes the control of water flow into an injection zone and the increase in efficiency of a pump system by utilizing downhole instrumentation and intelligent systems for monitoring and control of the oil/water separation process. The intelligent system is composed of an artificial lift system, permanently deployed instrumentation for fluid and equipment monitoring, completion hardware based on an electric tubing-to-tubing choke valve, and a hydrocyclone-based oil/water separator.
P. 603
Downhole Diagnosis of Drilling Dynamics Data Provides New Level Drilling Process Control to Driller
Authors: Heisig G. , Sancho J. , Macpherson J.D. 
Published: December 2007

Abstract
Vibrations are inevitable in drilling. However, the severity of vibrations and their detrimental influence on the drilling process depends on bit and Bottom Hole Assembly (BHA) design, the formation being drilled and, most importantly, the choice of drilling parameter such as WOB and RPM. When adjusting the drilling parameters the driller very often relies solely on his experience which (in the best case) is gained on offset wells.
A new Measurement-While-Drilling (MWD) based service significantly improves this situation by providing real-time feedback about the drilling process to the driller. A downhole tool containing various dynamics sensors, and a high speed data acquisition and processing system, continuously monitors BHA vibrations and diagnoses the occurrence of vibration related problems such as stick-slip, whirl, bit bounce etc. The type and severity of the diagnosed vibration are transmitted to the surface and displayed on a rig floor monitor. This allows the driller to take immediate remedial action by changing drilling parameters and, more importantly, optimize the entire drilling process.
This paper presents both the downhole tool and the surface display as well as the overall service concept. The downhole processing algorithms are also outlined. Several results from first downhole runs show how dynamic dysfunctions are identified and assessed downhole.
P. 649
Modelling and Interpretation of Condensate Banking for the Near Critical Cupiagua Field
Authors: Lee Sheng-Tai , Chaverra Marcial 
Published: December 2007

Abstract
Near-well condensate banking has been recognized as a main factor causing deliverability loss of condensate wells. The problem is particularly acute for low-permeability high-yield condensate systems. The very high-yield nature of the hydrocarbons leads to a significant condensate dropout once the reservoir pressure becomes lower than the original dew point pressure. The low-permeability rocks, in turn, cause significant pressure drops, exacerbating condensate banking.
This paper presents a fundamental study on the mechanisms controlling deliverability of low-permeability condensate wells in the giant, near-critical Cupiagua field in Colombia. The study combines results from three areas of work, namelyinterpretation of long-term (approximately six months) well production and build-up test data for three appraisal wells,fine-grid radial single-well equation-of-state compositional modelling of the long-term well test andrigorous application and validation of the single-well pseudo- steady-state-flow theory to predicting production rates of condensate wells.
First, we present compositional modelling work to history match the production test data (e.g. GOR and production rates versus time) for three rich-condensate wells. The history-matched compositional model is then used to analyze the in- situ phase behavior and condensate banking phenomena during production. The analysis of model results provides a clear understanding on the key factors which control well deliverability. Particularly, we have found that in-situ condensate revaporization is directly related to increase of production GOR and loss of deliverability. The factors which affect revaporization are then investigated through the compositional model.
The well-known pseudo-steady-state theory for flow of single-well condensate wells is then re-examined with the aim of using the simple pseudo-steady-state formulation to calculate the deliverability of condensate wells. It is demonstrated that the in-situ phase behavior and PYT properties calculated by the pseudo-steady-state model match closely those from a general EOS compositional model. Further, the pseudo- steady-state model is shown to be applicable beyond the infinitely-acting-reservoir flow period, within which the GOR is constant. Application of the pseudo-steady-state model is demonstrated using a set of field-measured production data.
P. 631
CFD Study of Bubble Carry-Under in Gas-Liquid Cylindrical Cyclone Separators
Authors: Erdal F.M. , Shirazi S.A. , Mantilla I. , Shoham O. 
Published: December 2007

Abstract
The Gas Liquid Cylindrical Cyclone (GLCC) is an attractive compact separator alternative to the conventional vessel-type separator. Thus, it is important to develop predictive tools for design and to be able to improve the technology of the GLCC. Previous studies on the GLCC have focused on mechanistic models capable of predicting the operational envelope for liquid carry-over and on the understanding of the flow field in the GLCC. The main objective of this work is to investigate the behavior of small gas bubbles in the lower part of the GLCC, below the inlet, and the related gas carry-under phenomena. This investigation was performed by flow visualization and by utilizing a commercially available computational fluid dynamics (CFD) code. Simulations of single-phase and two-phase flow were carried out and bubble trajectories were obtained in an axisymmetric geometry that represents the GLCC configuration. Flow visualization experiments and CFD simulations indicate that the flow field in the GLCC below the inlet is very complex. Bubble trajectory analysis was used to quantify the effects of the important parameters on bubble carry-under. These include bubble size, ratio of the GLCC length to diameter, viscosity, Reynolds number, and inlet tangential velocity.
P. 781
Permeability Simulation in Poor Sampling Conditions
Authors: Guerreiro L. , Almeida A. J. , Soares A. 
Published: December 2007

Abstract
To build a reservoir geostatistical model for permeability, it is necessary to have accurate values provided by core measurements. Unfortunately, in most cases the cored zones are a very small proportion of the total length of a well. Standard regression procedures are commonly applied to find relationships between log porosity values and core measurements in order to estimate permeability in the non cored zones. In reservoirs where the relationship between porosity and permeability cannot be derived with standard regression techniques, Probability Neural Networks (PNN) can be an alternative as shown in this paper. The PNN calculate all linear and non-linear relationships between multi-variables. The output is a probability of a point (unsampled core) to belong to a given class of permeability.
In a second step, after having generated classes of permeability (stochastic simulation of a categorical variable) in the whole reservoir, another simulation (Probability Field Simulation) is applied to obtain permeability values maintaining its spatial continuity. The method developed and described in this paper preserves the heterogeneity and spatial continuity of extreme values of permeability and the spatial continuity of data.
Factors Influencing Oil Demand and the Range of Call on Middle Eastern Crude production in 2010
Authors: Jordan Roy M. 
Published: December 2007

Abstract
The world should be grateful to those who work in the oil and gas industry, particularly to those in the upstream sector, who everyday encounter the challenges posed by the barren desert, the swamps and jungles, the offshore storms and the technological complexity of deepwater exploration and production. All this in order to ensure that oil is available to the consumer whenever and wherever it is wanted. In achieving this objective the industry has an outstanding record of efficiency. Yet public gratitude and popularity are not sentiments generally associated with the oil and gas industries. There are several explanations for this.
An Integrated Uncertainty Analysis for the Development of an Offshore Gas Condensate Field
Authors: Govan Alastair H 
Published: December 2007

Abstract
To evaluate reservoir development projects it is common practice to use reservoir simulation models which provide a detailed description of the reservoir performance based on a single reservoir description. Since such models are frequently very large and require considerable computing resources, it may not be possible to consider more than one or two alternative models. As a result, there is often a very poor understanding of the uncertainty in the predictions which have been obtained. Furthermore, even in situations where sufficient resources are available to run a large number of simulation cases, there is often no methodology for combining the results to produce a probabilistic view of the range of outcomes.
This paper describes a method for integrating the uncertainties in a project, including uncertainties in costs, tariffs and product prices as well as subsurface uncertainties such as fluids in place, reservoir communication and well deliverability. The method is illustrated by application to an offshore gas condensate field which is in the early stages of development planning.
Implementation of No Leak Policy in Bahja/Rima Area
Authors: Al-Wardy Ali 
Published: December 2007

Abstract
In 1995 Petroleum Development Oman (PDO) introduced a no leak policy for its activities. As result a review was carried out to assess the optimal way to implement the policy in all operational areas where potential for leaks existed.
One of the main causes of the leaks in PDO's production environment is flowline degradation due to the effect of internal and external corrosion.
A study carried out by PDO showed that one of the worst areas for flowline leaks in South Omam was the Rima field which had experienced sever corrosion problems in certain flowlines because of high H2S, CO2 and O2. Flowline life was less then 3 years, with some flowlines failing after only 3 to 6 month of service.
Following a successful trial, Reinforced Thermoplastic Pipe (RTP) is now being used instead of carbon steel as the flowline material in Rima. This paper describes the no leak policy implementation in Bahja Rima area and the trail and the subsequent evaluation which shown that RTP is feasible and commercial alternative to traditional flowline material.
An Improved Oil Recovery Study of Supplemental Down-dip Gas Injection, Peripheral Water Injection, and Crestal Gas Injection in a Middle East Layered Carbonate Reservoir
Authors: Mitri Karim T. , du Cray Renaud Perret 
Published: December 2007

Abstract
A 9 pseudo component compositional simulation study (Quarter of a full field radial) for a very mildly dipping, slightiy undersaturated, Middle East carbonate reservoir, has indicated down-dip gas injection yields recovery benefits, at relatively higher sustainable rates as supplemental to a water injection scheme or as a stand alone strategy. Common to all scenarios was crestal gas injection at the only existing gas injector.
Since miscibility is not maintained throughout in the reservoir, the impact of sweep on oil recovery is dominant again. Interfacial tension (EFT), as a miscibility indicator was used to help characterize the run results. Improved reservoir characterization models are a pre-requisite for optimization of miscible and near-miscible Gas injection processes.
Enhanced Profitability with Non-Conventional IOR Technology
Authors: van Domelen M. S. 
Published: December 2007

Abstract
The tenu Improved Oil Recovery (IOR) is loosely defined in the petroleum industry. Conventional IOR methods include improved reservoir management, cost reduction initiatives and advanced methods traditionally referred to as Enhanced Oil Recovery (EOR) or tertiary recovery The Norwegian Petroleum Directorate (NPD) defines IOR as "actual measures resulting in an increased oil recovery factor from a reservoir as compared with the expected value at a certain reference point in time." The NPD definition, which focuses on the concept of a reference point in time, implies that technological advances over the life of a project can be defined as IOR techniques.
This review paper will focus on the use of well technologies that traditionally were not considered IOR methods. Well-documented case histories will be presented which illustrate how the integrating of completion and stimulation design can result in enhanced profitability. Applications include: The successful completion of a deep, low permeability reservoir. This case history summarizes how state-of-the-art completion and stimulation in the early 1980's was not economical. With technological advances, however, a world record fractured horizontal well, which was completed in the 1990's, allowed the reserves to be economically produced.The use of a novel multi-stage completion/stimulation tool which allowed overall well costs to be reduced by dramatically reducing rig time.The use of suatigraphically horizontal wells in high-relief chalk reservoirs to make marginal fields in the North Sea economical.
This paper provides technology transfer by highlighting successful case histories from various locations. The importance of integrating completion and stimulation design is clearly illustrated. The necessity to evaluate total project profitability as opposed to individual components is emphasized.
Experiment of Despatching Enhanced Oil Production Through Existing Pipeline with Limited Throughput by The Use of Drag Reducing Agent
Authors: Sultan Emad , Ahmed K. Z. N. 
Published: December 2007

ABSTRACT
KOC currently produces an oil field in Area A. Its production is despatched to a Tank Farm about 70 miles away through 2 nos. 30 inch transit lines. These lines are capable of handling 300 MBOPD each within the current maximum allowable working pressure of 415 psig.
It is planned to increase the daily production in Area A and sustain it for a decade or so.
Since this rate is above the current combined capacity of the two transit lines, it dictated the requirement of a third transit line.
In an attempt to explore alternative means to despatch the additional production, it was decided to examine the feasibility of enhancing the capacity of the existing lines within their pressure limitations by using Drag Reducing Agents. If found feasible this would mean substantial reduction in capital investment either by eliminating the need for a third line or reducing its diameter.
Accordingly a test was carried out in Transit Line 1 under KOC supervision by a vendor company.
The test showed that drag reduction of 55% could be achieved with 16 ppm and 68% with 34 ppm of the chemical and during the test the entire available crude could be pumped through transit line No. 1 well below its MAOP.
Data generated in the test showed that the 2 nos. 30 inch lines are hydraulically capable of handling the predicted enhanced peak production with DRA injection at appropriate ppm in both the lines.
Innovative Completion Design For Multizone Gas Injectors
Authors: Le Gurun Ludovic , Helderle Paul 
Published: December 2007

Abstract
The design for a multizone gas injector well has to take into account many parameters, i.e. tubing size, injection velocity, erosion, corrosion, scale deposits, zone isolation by wireline without loss of diameter, possibility of permanent logging and stimulation flexibility. The experience built on oil well producers helped a lot in choosing the appropriate equipment. Also some items had to be identified or locally modified to suit the anticipated requirements.
Production Logging in Multi-Lateral Wells – Interpretation, Problems and Solutions
Authors: Sufi Ahmed W. , Kumazaki Yoshi , Haq Shahid A. 
Published: December 2007

Abstract
Multi-lateral wells are being employed to improve vertical sweep by enhancing productivity/injectivity from relatively tight sub-layers of the reservoir. In addition, different direction and orientation of the drilled laterals improve areal sweep. To optimize the development plans for multi-layered reservoirs with varying permeability, quantifying the contribution across each sub-layer is necessary and can be achieved by production logging. These surveys are being conducted in Zakum Development Company (ZADCO) as part of the field development plan.
Production logging data from multi-lateral wells are often difficult to interpret due to multi-phase flow. A variety of flow patterns exist in multi-phase production. These flow patterns can vary within a particular wellbore, even at constant flow rate. Quantitative analysis is difficult in such cases sometimes, however qualitative information can be inferred. The conventional production logging technology has its limitations in analyzing the data. The analysis is dependent and based on several factors. Some of these factors are drilling/completion and the wellbore damage as a result of drilling fluids, stimulation and cleanup, the production logging tool and analysis techniques.
This paper highlights the details of above factors and how these can be handled. Also, two case histories are included to indicate the problems observed.
Design of Action Plan and Monitoring Program; Secondary and Tertiary Gas Injection Pilots in a Limestone Reservoir
Authors: Al Hendi Ahmed , Boyd Douglas , Al-Riyami Ahmed 
Published: December 2007

Abstract
This paper documents the design issues and considerations of a miscible gas flood monitoring program planned in 1999. The objective of the monitoring program is to assess the efficiency of gas injection as a viable means to increasing oil recovery.
Based on simulation findings, it was decided to carry out three pilots; two secondary and one tertiary miscible gas injection in three sub-reservoirs.
The pilots were designed to provide information for a future Full-Field Development Plan (FFDP). Intensive data gathering and monitoring is planned to: 1) diagnose and rectify unforeseen events early in the life of the project, and 2) evaluate each individual pilot's performance. Monitoring is planned through the pilot's wells, nearby wells and two new dedicated observation wells.