bluuebunny/crossref_metadata_2025_split huggingface dataset:
A New Correlation For Two Phase Inflow Performance Relationship in Horizantal Wells
Authors: Al-Hussain Ali Musa , Hossain M. Enamul 
Published: March 2015

Abstract
Petroleum engineers are routinely required to estimate the production behavior of individual oil wells. Having an idea of the pressure-rate behavior enables engineers to evaluate various operating scenarios to ascertain the optimum production scheme. This also facilitates understanding how to design and install surface and subsurface production equipment whenever necessary. Knowledge of pressure-rate behavior is necessary for designing and evaluating stimulation treatments, or any operation that might improve flow efficiency. Estimates of future performance are also required for forecasting and planning purposes. The actual production mechanism and reservoir flow regimes around the horizontal well are considered more complicated than those for the vertical wells. Some combination of both linear and radial flow actually exists in the horizontal well. In literature, several authors such as Bendakhlia and Aziz, Cheng, and Retnanto and Economides concluded that the shape of measured inflow performance relationships (IPRs) is similar to the estimated IPR by Vogel. This paper critically evaluates the following analytical equations: modified Vogel's equation, Cheng's equation, Bendakhlia and Aziz's equation, and Retnanto and Economides' equation. These existing models are used to estimate the inflow performance relationship of two-phase flow in horizontal wells. In addition, a new correlation is presented for two-phase flow in horizontal wells that has fewer errors and is better fitting compared to the other correlations in the literature mentioned above. After the filtration process, a total of 62 sets of downhole production data were used for 18 horizontal wells. This data was utilized to evaluate the current two-phase IPR correlation for horizontal well. The data is also used to develop a new correlation that has less errors comparing with existing correlations and shows better fitting. A new classification range of 1 5 &lt; P I &lt; 1 5 is used in this study. For PI &lt; 15 it was observed that Cheng's then Bendakhlia and Aziz's equations were the best with an error of 12.9% and 13.3% respectively. The Retnanto and Economides equation did not fit with the used data, which has an error of 93%, while the proposed correlation was the best compared to others with an error of 11%. For PI &gt; 15 the following was noticed: Vogel's then Bendakhlia and Aziz's equations were the best with errors of 26% and 30%, respectively. Retnanto and Economides equation did not fit with the used data, which has an error of 207%, while the proposed correlation shows the best compared to other equations with an error of 13%.
Next-Generation Modeling for Long-Term Development Planning: Case Study
Authors: Marir Boualem , Allouti Abdelkader , Bedewi Mahmoud 
Published: March 2015

Abstract
In conventional modeling, the flow from the reservoir to the wellbore is decoupled from the flow in the surface pipelines and the facilities. This approach is sufficient during history matching; however, it is less accurate for future performance predictions where precise hydraulic calculation is necessary to assess the pipelines and facilities design.
This paper studied an offshore green field where production from six different reservoirs in which several single and multilateral horizontal wells are drilled and connected to offshore wellhead towers being connected by pipelines to an infield super complex. Because surface facilities are shared by all reservoirs and the field is being developed as a gas self-sufficient field wherein the processed gas from the first stage of separation, after removing the fuel, must be re-injected, it has been recognized that conventional modeling is not appropriate for defining the long-term development plans (LTDP) in addition to identifying major development and operation risks related to the subject field.
To take into account the impact of the surface facilities on the predicted field performance, a next-generation modeling approach was used to fully integrate the subsurface models with the surface model. Additionally, as the five-spot water injection pattern is the development scheme for one of the primary reservoirs, streamlines simulation using the integrated multi-reservoirs model was performed to define the performance of the different injection patterns and to rationally optimize use of the surface injection facilities.
The subject multi-reservoir model was also used as a tool for risk mitigation plans for potential major gas production; different approaches were proposed and assessed in an attempt to define the possible plans for using the excess produced gas without negatively impacting the field's oil recovery.
Perforating Strategy Change in High Deviated and Horizontal Wells in North Kuwait – Tractor Conveyed Perforations in Kuwait
Authors: Awad M. Omar , Al-Ajmi Moudi F. , Al-Mutairi Moute'a , Bradford Colin , Shukla Pinakin 
Published: March 2015

Abstract
The Raudhatain Zubair reservoir play a key role in the production development plan for North Kuwait. The Zubair production is contributing 20% of total north Kuwait production.
Well RA-XX3in North Kuwait Raudhatain field, produced a significantly higher oil rate than existing wells in the field. Production was the application of the latest perforating technologies comprising of deep penetrating charges along with the unique Perforating for Ultimate Reservoir Exploitation and Dynamic Under balance (DUB). The charge used is the deepest penetrating charge available in the industry today, based on API-19B section 1, with penetration depth of 65.2″. Prior existing wells produced an average of 1500 BOPD. This well after being perforated using Dynamic Under balance (DUB) and deep penetrating charges produced 3000 BOPD with zero water cut.
The interval perforated was in a high deviated well where traditionally a Tubing Conveyed Perforation (TCP) deployment would have been used to convey guns with a static under balance, correlating the gun positioning with a RA marker more than 2000 ft above the interval. Using the wire line tractor, the guns were positioned accurately on depth, utilizing DUB technology, with significant rig time saving over the conventional TCP runs.
A further three wells have been shot using this conveyance method and has shown to provide significant rig time saving with additional production due to DUB technique and accuracy of gun positioning.
This SPE paper and presentation will demonstrate the effectiveness and efficiency of deploying guns using WL tractor and benefits of DUB perforating. This successful operation has provided a new approach to underbalanced perforating on tractor to achieve clean, zero-skin perforations is replacing the prevailing underbalanced concept of perforating job design.
Focused Engineering Initiative Produces New 16-in Roller Cone TCI Design to Solve Carbonate Drilling Challenges in Northern Kuwait
Authors: Al-Enezi Dakhil , Sounderrajan Mahesh , Boukhamseen Ali , Al-Safran Sarah , Hassan Said , Nair Prakash , Ghoneim Osama , Bits Smith 
Published: March 2015

Abstract
Interbedded formations with vastly different compressive strengths and blind drilling are two distinct challenges the operator must solve constructing a 16” hole section in Northern Kuwait. These issues can lead to cutting structure damage to roller cone bits resulting in low performance and downhole tool failure. In addition the operator strives to achieve fast ROP by applying high weight-on-bit (WOB) through the hard Dammam to Mutriba carbonate sections which can also cause damage to the tungsten carbide insert (TCI) bit's cutting structure.
To manage the challenges, the operator's drilling team working in conjunction with the bit supplier launched a performance improvement initiative. The carbonate application was analyzed using finite element analysis (FEA) based dynamic simulation program to fully understand how to stabilize the bit in different downhole conditions and improve hydraulic efficiency. Based on the computer analysis and field run data, a new stable bit was designed.
The new bit includes a specialized cutting structure configuration, improved hydraulics and optimized insert carbide grades to mitigate impact damage. A patented double sealed bearing was also utilized to improve durability and seal reliability
The new roller cone bit design was run with an optimized drilling plan setting a record rate of penetration (ROP) in its first test run. The new bit design has enabled the operator to drill a challenging carbonate section of 4775 ft from Shoe to total depth (TD) with a record penetration rates (ROP) of 65.8 ft/hr achieving 7.7 % increase in ROP over the best performance in the same field. The authors will discuss the application challenges, analysis and resulting performance improvement.
Fracture Cleanup Determination by Guar Measurement in Flowback Water Samples
Authors: Al-Saihati Ali H. , Hajj Hicham El , Ortiz Rick , Bittar Michael , Shakeel Muzzammil 
Published: March 2015

Abstract
Hydraulic fracturing is a well stimulation process used to maximize production of oil and natural gas. It is used to create new fractures and enhance in-situ subsurface fracture systems as well to allow oil or natural gas to move more freely from the rock pores to the production wellbore. The post-fracturing flowback procedure is critical to the production performance of a fractured well. An improper flowback cleanup often leads to lower retained conductivity near the wellbore, resulting in reduced production. Controlled flowback is beneficial for properly removing polymer gel residue from the proppant pack. The degree of propped fracture cleanup is related to a number of factors that relate to the measurement of guar polymer contained in the fluid flowback samples. Measurement of guar carbohydrate from fluid flowback samples is used to estimate the amount of guar recovered after fracturing treatments. Using a field study and laboratory analysis, this paper demonstrates that the measurement of the guar polymer in fluid flowback can be used as an indication of fracture cleanup. The Anthrone method, a technique for measuring total guar carbohydrate in the fluid flowback samples, is used. Anthrone dissolved in sulfuric acid forms a yellow solution. In the presence of guar or its derivations, the solution turns green/blue. Using an ultra violet (UV) spectrometry technique, guar concentration in the fluid flowback samples can be determined from the intensity of measured color. Many fluid samples collected from two wells were analyzed and results are presented. A good correlation between the guar polymer concentration and cleanup is observed and quantified. Results from this study show that using this technique can result in an optimum flowback design that maximizes near-wellbore (NWB) conductivity and fracture cleanup for better production.
Design, Execution, and Results of the First Multi-Zone Cased Hole Gravel-Pack Completion in West Malaysia
Authors: Hareezi Adam , Hamid Afiq B , Samuel Orient B. , Syafei Djuhana B , Khalid M Zaidan , Jabar M Zawawi , Abidin Reduan Zainal , Noorizan Airin Basha , Gil Joel , Saebi Shahryar , Wallace Cal , Sharji Nasser As , Khai Tan Chun 
Published: March 2015

Abstract
This paper illustrates the design and application of tools and procedures for successful execution of the first Multi-zone Cased Hole Gravel Pack Completion in West Malaysia utilizing Alternate Path (Shunt Tube) Technology with Isolation System to enable access to multiple reserves and maximize reservoir contact in “A” field.
The single trip gravel pack system allowed multiple stacked zones to be completed with reduced completion operation time. The “A” field, predominantly consisting of unconsolidated stacked layers has tendency to produce formation fines and sand and historically, gravel pack has proved as the most appropriate sand exclusion method for this field. Considering the distance between the adjacent zones (upper zone was approximately 120m distance from the middle zone), shunt tube technique was selected as the most suitable method for achieving uniform and high packing efficiency.
Several options were examined for the completion to select a technology to have a proven cost effective solution to cope with different intervals space out far distance. The multizone shunt tube system has an intensive record of accomplishment in the oil and gas industry and has been used in Malaysia with excellent results. It was a very attractive technique to use because of its simplicity and cost-effective approach of completion of multiple intervals. Proppant placement with 100 percent packing efficiency along 227m of 3 different zones was critical for the success of the project. Shunt tube configuration was optimized by selectively plugging and unplugging nozzles to efficiently distribute the proppant to all 3 intervals. This technique added high value to the success of the operation and ensured any bridges in the annulus were bypassed during gravel packing treatment.
The gravel packing carrier fluid also plays an important role when using shunt tubes. The system needs a viscous fluid to suspend and carry proppants to the perforations and form a competent and compacted pack without damaging the treated zones. For this reason, a Non-polymeric and solid free VES (viscous elastic surfactant) was chosen. The selected carrier fluid has been used in propped fracturing as well as gravel packing with excellent results as it has exceptional gravel carrying capability and leaves high formation retained permeability resulting in significantly low skin due to the unique capability of breaking when exposed to small amount of liquid hydrocarbons thus eliminating the requirement for breakers (Sullivan et al, 2006. Parra et al, 2009. Shahryar et al, 2010).
Artificial Intelligence Based Estimation of Water Saturation Using Electrical Measurements Data in a Carbonate Reservoir
Authors: Bageri B.S. , Anifowose F.A. , Abdulraheem A. 
Published: March 2015

Abstract
Good estimation of water saturation is necessary for successful estimation of reservoir properties as it minimizes the error in initial oil-in-place calculations. Electrical measurements on core plugs have been used to predict water saturation by analyzing the parameters of Archie's equation. Presently, several methods such as conventional, CAPE (1, m, n), CAPE (a, m, n) and 3D methods have been used to analyze the parameters. However, the accuracy of these methods has become inadequate for optimal estimations. Recent successful applications of Artificial Intelligence (AI) techniques in petroleum engineering have confirmed the capability of AI to handle such non-linear and complex industrial problems. Interestingly, the new paradigm of employing AI for water saturation estimation has not been sufficiently addressed in the petroleum engineering technology application literature.
This study focuses on the use of the predictive capabilities of Artificial Neural Networks and the Fuzzy Inference Engine. 378 data samples obtained from the laboratory measurements of electrical properties of 41 core plugs taken from Carbonate reservoir rocks in the Middle East were used for the implementation of the proposed techniques. Using the popular stratified data sampling method, 70% of the data points were used to train the AI models while the remaining 30% were used for validation and testing.
The comparative results showed that the AI models performed better with higher accuracy and lower errors than those obtained with the current methods. Based on this result, we conclude that Fuzzy Logic exhibits a robust predictive capability for the estimation of water saturation from electrical measurements by providing a good match with the core values and giving better error distribution than the other AI and current methods.
Water Complex Permittivity Model for Dielectric Logging
Authors: Donadille J.M. , Faivre O. 
Published: March 2015

Abstract
In recent years, high-frequency dielectric tools have become an increasingly accepted service for providing saturation, water salinity, and textural information. To obtain these petrophysical quantities from the measured dielectric data, a mixing law is used that relates the bulk formation complex permittivity (relative permittivity and conductivity) to the constituents of the system, including the water present in the pores. Several mixing laws have already been published in the literature. This paper is concerned with an integral part of all of them, which is the prediction of the water complex permittivity as a function of salinity, temperature, and pressure.
The water complex permittivity is known to vary with salinity, temperature, pressure, and frequency of operation. We have established a dielectric water model as a function of these four quantities, and have recently validated this model with dielectric laboratory experiments on several water samples at high temperature and pressure. In this paper we fully disclose the model so that it can be used and adapted by the industry.
We also demonstrate with a sensitivity analysis that using the correct water model is critical to the accuracy of the final petrophysical outputs.
Case History: New Horizons for Downhole Flow Measurements via Coiled Tubing Equipped with Real-Time Downhole Sensors at South Ghawar Field, Saudi Arabia
Authors: Buhassan Shaker , Halder Surajit , Tammar Hassan , Beheiri Faisal , Ahmed Danish , Brown George , MacGuidwin Jeffrey Thomas , Haus Jacques , Moscato Tullio , Molero Nestor , Manzanera Fernando Baez 
Published: March 2015

Abstract
During the last 5 years, one of the most common matrix acidizing enhancement techniques used to improve zonal coverage in open hole or cased hole wells is conducting a distributed temperature survey (DTS) using coiled tubing (CT) equipped with fiber-optic and real-time downhole sensors during the preflush stage before the main stimulation treatment. This is used to identify high and low intake zones so the pumping schedule can be modified to selectively place diverters and acidizing fluids with a high degree of control. Once stimulation treatment has been completed, a final DTS analysis is performed to evaluate the zonal coverage and effectiveness of the diversion. Even though this technique has provided satisfactory results, alternative methods providing faster and more accurate understanding of flow distribution between the zones and laterals are needed, especially if there is limited temperature contrast between fluids and reservoir. Thus, an innovative coiled tubing real-time flow tool has been recently developed to monitor flow direction and fluid velocity. This measurement is based on direct measurement of the heat transfer from the sensors to the surrounding fluid using a calorimetric anemometry principle. The first worldwide use of this technology in a Saudi Aramco injector well showed this to be a viable new approach to downhole flow monitoring that can be used by itself or in conjunction with DTS, depending on the constraints of each individual intervention.
Mechanical Properties of Carbonate Formation and Their Influences on Drilling and Hydraulic Fracture Modeling
Authors: Hamid Osman , Rahim Zillur 
Published: March 2015

Abstract
Among many challenges encountered during drilling and hydraulic fracturing operations in carbonate reservoirs, wellbore stability related issues while drilling and variability and unpredictability of the outcome of hydraulic fracturing are the most significant ones. Accurate characterizations of the mechanical properties are essential to understand how the carbonate reservoirs respond to these issues. Static mechanical properties can be obtained directly in the laboratories from triaxial tests on core samples, while dynamic properties can be calculated from wireline measurements such as acoustic wave velocities and bulk density of the formation.
Core plug samples from Field-A producing carbonate B and C reservoirs were tested for acoustic and mechanical properties using triaxial method. Laboratory studies on the elastic and deformational properties of carbonate B show that this formation exhibits wide range of elastic properties due to heterogeneity, while the trend in carbonate C is much clearer.
This study enabled the generation of empirical correlations among different properties, such as density and P-wave velocity, P and S-wave velocities, P-wave velocities to static and dynamic moduli and Unconfined Compressive Strength (UCS). The correlations show a good agreement with available correlations that are commonly used in the industry for carbonate C. The developed equations will improve and enhance hydraulic fracture and wellbore stability models that are related to geomechanics in the carbonate reservoir. The equations compute the mechanical properties for any well within the study area using measured geophysical log data such as density and compressional and shear sonic logs. The derived correlations are implemented in actual cases and are presented in this paper.
Challenges and Solutions to the North Kuwait Jurassic Dynamic Modeling
Authors: Sharifzadeh Ahmad , Daoud Ahmed , Amari Mustafa , Dashti Qasem , Al-Enzi Bashayer 
Published: March 2015

Abstract
North Kuwait Jurassic Complex consists of 6 fields with 4 major reservoirs. Total of 19 integrated reservoir models incorporating seismic, geological, petrophysical, and engineering data have been constructed to delineate the reservoirs and perform multi-scenario production forecast for the whole field. These models are dual porosity, with near critical fluids of gas condensate and volatile oil. There are different challenges to model the whole fields that can be summarized as follows. First, the two main producing reservoirs among all fields are (RA) and (SA) which account for about 40% of the hydrocarbon in place. These two fields show existence of different free water levels (FWL) along the areal extension of both fields without any evidence of compartmentalization based on pressure data. Second, all the asset is producing towards one common facility where some fields are gas condensate and some other is volatile oil. Third, modeling the fields using compositional simulator with dual porosity system will complicate the models and increase the running time.
This paper explains the approach adopted to solve most of these challenges. First, a numerical approach was implemented to allow communication between these blocks of different FWL's at the hydrocarbon zone only. Thus, ensure the equilibration of the system with honoring the geological understanding and allowing pressure communication through the hydrocarbon leg. Second, a proposed approach of using the standalone simulation models for running different sensitivities to select the optimum development plan per each field and then couple them with one controller at the surface to get the optimum field development plan for the whole fields as one asset producing through one common surface facility. Third a black oil delumping approach was used to convert the black oil to 35 pseudo components based on different EOS models generated per each field. Thus getting the advantage of speeding up the run based on using black oil simulation and reporting the change in composition with time using a simple black oil delumping look up table.