Hydraulic Horsepower Research Articles

EVALUATING CUTTING TRANSPORT ON 12 ¼” SECTION WELL TM-1

Mud hydraulics on a 12-1/4" section needs to be planned properly. Mud hydraulics design on a 12-1/4" section includes determining mud density, flow type, pressure loss, pump specifications, bit hydraulics and cutting lifting design. The purpose of bit hydraulics design is to determine the optimum flow rate. Mud hydraulics optimization is carried out using methods the Bit Hydraulic Horse Power (BHHP), Bit Hydraulic Impact (BHI) and Jet Velocity (JV) methods, where the analysis is in the form of graphs. The graph is analyzed by using a trial and error method to obtain the recommended flow rate so as to provide good cutting lifting. where the expected recommendation analysis are Cutting Transport Ratio (Ft) > 90%, Cutting Concentration (Ca) < 5%, and Carrying Capacity Index (CCI) > 1. The analysis results from the graph show that for the hole 12-1/4", it is recommended to use an optimum flow rate of 626.6 gpm with minimum value of Ft is 90.01%, Ca is 0.87% and CCI is 1.95. These values are stated to be good by using 15-15-16 nozzle bit combination. The Flowrate value can be increased up to 785 gpm by using 18-18-20 nozzle bit combination.. Keywords: Hydraulic Mud Planning, Optimum Flow Rate, Cuttings Removal.

Hole Cleaning during Drilling Oil and Gas Wells: A Review for Hole-Cleaning Chemistry and Engineering Parameters

Efficient hole cleaning during drilling operations is critical to maintain a high rate of penetration and smooth drilling, leading to minimum drilling problems and economical drilling efficiency. This process involves several important factors, including pipe-sticking incidents, higher cuttings concentrations in the annulus, noisy vibration of the drill string, erratic equivalent circulating density, lost circulation incidents, well control incidents, geomechanical hole section instability, tight spots during tripping operations, and excessive usage of chemical additives for conditioning hole sections and mud. Various approaches, including correlations, methodologies, developments, algorithms, equipment, charts, field experience, chemicals, and studies involving experiments, can be used to enhance the efficiency of hole cleaning. The development of hole-cleaning models is important for use as hole-cleaning indicators to ensure optimized drilling efficiency. This paper presents a comprehensive overview of the complex field of hole cleaning in the oil and gas industry. It includes techniques, tools, models, and chemical additives. It also encompasses drilling engineering, operations, and chemistry. To facilitate the transit of drill cuttings, maintain hole section stability, cool and lubricate the drill bit, and transmit hydraulic horsepower, this article outlines the important roles of drilling fluids. The significance of chemical additives, including nanoparticles, natural and modified polymers, and synthetic polymers, in preserving wellbore stability, improving drilling efficiency, and lowering drill bit wear is also covered in the study. It concludes by making recommendations for further study to clarify hole cleaning for the reader to facilitate and boost drilling efficiency.

A novel method for preventing technical challenge during drilled cuttings/produced water reinjection: An injection rate management tool

Drilled cuttings reinjection (DCRI) is arguably the most cost-effective technique for disposing of drilling wastes, especially under the zero-discharge policy. However, there are many failed operations due to technical issues related to surface pumps and annular pressure. Currently, there is no sophisticated model for predicting an optimum injection rate that prevents technical failure during DCRI. The practice of using an arbitrary rate is not based on sound engineering principles and may be unable to prevent annular or pump failure. This is because operators do not relate the injection rate to the Maximum Allowable Surface Pressure (MASP) and/or the Maximum Allowable Annular Surface Pressure (MAASP). Due to these limitations, operators seek to find new methods to handle DCRI through the annulus. Thus, this study was carried out to derive a model systematically for the optimum injection rate to prevent technical challenges during DCRI. The components combined include the mechanical energy balance (MEB) and the model for hydraulic horsepower (HHP). The MEB between the wellhead and the annulus was used to derive a model for the annular pressure. Mechanical equilibrium between the STP and the MASP was used to generate another equation, based on the HHP. Then, the new expression was substituted into the annular pressure model. Lastly, the optimum rate was derived based on mathematical principles. The results applied to Well B of the Niger Delta showed a value (2.95 Bbl/min or 675.37 m3/day) that is consistent with the existing field database, and outperformed other related models for flow rate. Simulation results showed that the annular size (78.8%), rheological parameters (12.4%), and MASP (2.9%) were the main factors that affected the optimum injection rate. Thus, we can apply a higher injection rate in larger annuli compared to smaller ones, and to maintain annular pressure simply ensure uniform annulus devoid of erosion/thermal effects.

A Hybrid Data-Driven/Physics-Based Modeling Approach for Hydraulic Fracture Initiation and Early-Phase Propagation in Shale

Optimal hydraulic fracture (HF) initiation and early-phase propagation results in minimal near-wellbore tortuosity, decreasing the likelihood of screenouts and maximizing the resultant well productivity. While most predictive models for the HF geometry produced in a treatment consider the far-field region, the near-well vicinity should be an integral part of a properly-engineered reservoir stimulation strategy. In this work, a novel hybrid data-driven/physics-based approach is elaborated for modeling HF initiation and early-phase propagation from perforated horizontal wells.A treatment-optimization scheme via oriented perforating is presented using the developed hybrid model, considering the orientation of the induced HF initiation (longitudinal or transverse with respect to a well drilled along the minimum horizontal in-situ principal stress) and the resultant formation breakdown pressure (FBP). Transverse HF initiation and early-phase propagation is ideal for wells drilled in low-permeability “tight” formations, while FBP minimization suppresses the overall on-site hydraulic horsepower (HHP) requirements. The demonstrated optimization scheme is applied separately to the in-situ stress states of seven prolific shale plays from the U.S. and Argentina, suggesting oriented-perforating strategies that target the promotion of transverse HF initiation in two of these (Barnett and Marcellus), while suggesting oriented-perforating strategies that target FBP minimization in the remaining five (Bakken, Fayetteville, Haynesville, Niobrara, and Vaca Muerta). The effectiveness of oriented-perforating can potentially be compromised by fracturing fluid leakages around the casing’s circumference, which is shown to hinder transverse HF initiation.The hybrid-modeling approach is also used to estimate fracture initiation pressure (FIP) values for the seven shale plays studied, indicating significant discrepancies with analytical expressions traditionally used to approximate these FIPs in modern HF computational simulations. This sets the basis for expanding this hybrid-modeling approach over a range of in-situ stress states, incorporating aggregate data-driven (numerically-derived) correction factors in order to compensate for inaccuracies in the analytical approximations, which comprise the physics-based core of the proposed hybrid model.

Analysis of Emissions Profiles of Hydraulic Fracturing Engine Technologies

Today, the oil and gas industry, and in particular hydraulic fracturing operations, have come under increasing pressure from regulators and the public to reduce emissions. As the industry evolves, oil and gas producers are in the position of evaluating alternative technologies which will support their objectives of reducing their overall emissions profile and carbon footprint. As a response, the deployment of technology and solutions to reduce emissions related to hydraulic fracturing applications has recently accelerated, creating various options to address these industry challenges. BJ Energy Solutions and West Virginia University have been working on the application and emissions characterization of various hydraulic fracturing technologies. A study was conducted to evaluate the efficiency and resultant emissions from various technologies, including natural gas reciprocating engines, diesel-natural gas dual-fuel engines, large (>24 MW) gas turbines, and direct drive turbines. The study involved the development of an emissions model with the purpose of estimating total emissions of carbon dioxide (CO2), nitrous oxide (N2O) and exhaust methane (CH4) slip, all Greenhouse Gases (GHGs), and converted to tons of CO2 equivalent emissions per day of operation. The model inputs are the required Hydraulic Horsepower (HHP) based on pumping rate and pressure for various shale play scenarios. The model calculates emissions from the TITAN, which is a direct-drive turbine model fielded by BJ, using data collected following U.S. Environmental Protection Agency (EPA) testing protocols. The model also calculates and compares other hydraulic fracturing technologies utilizing published Original Equipment Manufacturer (OEM) data. Relevant EPA-regulated criteria emissions of oxides of nitrogen (NOx), Carbon Monoxide (CO) and Particulate Matter (PM) are also reported. Modeling results demonstrated that in most cases, the TITAN gas turbine system has lower total GHG emissions than conventional diesel and other next-generation technologies, and also has lower criteria emissions. The benefits of the TITAN gas turbine system compared to the other technologies stems from significantly lower methane slip, and the high-power transfer efficiency resulting from directly connecting a turbine to a reciprocating pump, despite the comparatively lower thermal efficiency.

Hydraulic Evaluation on 17 ½ inch Hole in Directional Well Y-1, Field Y Using BHHP Method

The evaluation of hydraulics carried out in a trajectory namely 17 ½ inches provides an overview of the hydraulic problems that occur with less-than-optimal pressure in the bit because it is less than the minimum percentage value that should be. which is less than 50%. it is affected by factors such as flow rate. mud weight. the rheology of the mud used and pressure loss both in the surface and sub-surface such as bit. pipe and annulus. So, optimization with the BHHP (Bit Hydraulic Horse Power) method becomes the next step to be taken in order for the drilling operation can perform better. It has been found from the optimization results that the CTR (Cutting Transport Ratio) method is a cutting analysis method that demonstrates the correct performance of the cutting transport process if the minimum percentage of 50% or higher is met. In addition, this method also takes the angle of inclination of a directional well Y-1 into one of the considerations. On the first trajectory. 17 ½ inch hole (1338.58 – 3166.01 ft) the pressure in the bit increased from around 22.83% to 31.14% at the initial condition to 56.20% until 56.59% with cutting transport results after being optimized up to 99%. The use of the BHHP (Bit Hydraulic Horse Power) method to optimize drilling hydraulics in the directional well is said to be successful because it produces an optimization value that is greater than the minimum standard which is 50%. Furthermore, the CTR (Cutting Transport Ratio) method to analyze the transport of cuttings to the surface has been running well showing the results that the cuttings have been successfully transported to the surface. Therefore, this method can be said to be successful with the acquisition of a value percentage above 50%.

Study The Effect of Proppant Concentration of Screen-Out Phenomena While Hydraulic Fracture Job

screen out is a blocking of the fracture path caused by bridging the path or accumulation of the proppant inside the fracture, clumping or lodging of the (solid particles) proppant across the hydraulic fracture width that causes to restrict formation fluid to flow into the hydraulically fractured formation. To avoid the screen out happening needing to save fracturing fluids, hydraulic horsepower. Conditions that leading to screen out during the hydraulic fracturing job in a well, such as, the ratio between the fracture widths to particle diameter that called (β), proppant concentration,  and wall roughness. The effects of these factors are investigated experimentally in the present work by building an apparatus that meet the shape of the real hydraulic fracture. The plugging time were measured and monitored through glass windows on both sides of the apparatus to follow the behavior of the proppant inside the fracture during the flow of the fracturing fluid or when the proppant plugs the fracture. To study the effect of the fracture wall roughness on the screen out phenomena, apparatus was build to get two different fracture shapes, to meet the real fracture wall in reality. Through the relation between the different proppant concentration and the plugging time, one can indicate on the graph the plugging region and non plugging region for different values of β, proppant concentration and fracture shape, in order to avoid the screen out. During designing the hydraulic fracture, the values of β were very important factor that can lead to screen out, through the results found that when β=1, the screen out happened very fast even at low proppant concentration, but for β=2, 3 and 4 the screen out depends on the proppant concentration and fracture shape. For β=5 it was found that, there is no screen out occurring for wide range of proppant concentration. The effect of hydraulic fracture wall roughness is important because it effect the speed of the suspension when passing through the fracture.

A new approach to maximising drill bit hydraulic horsepower

A new approach to maximising drill bit hydraulic horsepower

CBM drilling technical parameter optimization methodology and software development: a case study of LUAN mining area.

Based on the leakage of the coalbed methane (CBM) drilling engineering practice of Luan mining area in China, the author determines the safe drilling fluid density range for the stable borehole wall based on borehole wall collapse and fracture pressure. Such parameters as the drilling fluid hydraulic parameters (including pump pressure, pump power and displacement, nozzle diameter, bit pressure drop, bit hydraulic horsepower, circulation pressure drop, impact force and jet velocity) and drilling parameters (including weight-on-bit, drilling rotary speed, bit tooth wear) in each borehole section are optimized. Taking the lowest drilling cost as the controlling target, the drilling parameter optimization model is designed and solved by the genetic algorithm. Furthermore, a software named "CBM borehole wall stability parameter design and optimization" characterized by visualization and applicable for drilling formation condition, which can be used to design and optimize the borehole drilling technological parameters, is developed. This program includes such modules as drilling fluid density prediction, drilling technology design, database management, user management and help. The developed software is proven to solve the drilling leakage effectively in the No.67 borehole practice, which can help drilling engineers to optimize CBM drilling technological parameters safely and quickly.

A new approach to maximising drill bit hydraulic horsepower

A new approach to maximising drill bit hydraulic horsepower

Implementation of Hydraulic Fracturing Operation for a Reservoir in KRG

This study focuses on procedures to enhance permeability and flow rate for a low permeability formation by creating a conductive path using the hydraulic fracturing model. Well data are collected from the Qamchuqa KRG oil field formation. A Fracpro simulator is used for modelling the hydraulic fracturing process in an effective way. The study focuses on an effective hydraulic fracturing design procedure and the parameters affecting the fracture design. Optimum design of fracturing is achieved by selecting the proper fracturing fluid with a suitable proppant carried in a slurry, determining the formation fracturing pressure, selection of a fracture propagation fluid, and also a good proppant injection schedule, using a high pump rate and good viscosity. Permeability and conductivity are calculated before and after applying the hydraulic fracturing. Fracture height, length, and width are calculated from the Fracpro software, among other parameters, and the production rate changes. From the results, it is observed that by using hydraulic fracturing technology, production will increase and permeability will be much higher. The original formation permeability is 2.55 md, and after treatment, the average fracture conductivity has significantly increased to 1742.3 md-ft. The results showed that average fracture width is 0.187 inch. The proppant used in this treatment has a permeability of 122581 md. The suitable fluid choice is hyper with an apparent viscosity of 227.95 cp, and the proper proppant type is Brady sand with a conductivity of 2173.41 md-ft. Fracture orientation from the Khurmala oil field in Kurdistan is vertical fractures produced at a depth of 1868 m. Fracture half-length, total fracture height, and average fracture width are 220 ft, 42 ft, and 0.47 inch, respectively. After fracturing, the maximum and average area of fracture are 33.748 and 17.248 ft2, respectively. The recommended pump hydraulic horse power is 3200 HHP, and the total required fluid is 1076.3 bbl. In this study, hydraulic fracture is designed, and then, it has been analyzed after that production is optimized.

Evaluation of drilling hydraulic calculation to the ability of bottom hole cleaning

In drilling operation there are two important matters that must be considered, which are the pumps and drilling fluid rheology that are influencing hydraulics drilling system. The major function of drilling fluid is to lift the drill cutting to the surface and still maintain the drilling hole to avoid an encounter. Evaluation of hydraulics drilling for bottom hole cleaning will count the parameter success which influence in removal of cutting to the surface for bottom hole cleaning and optimization drilling calculation hydraulics. The velocity of drilling fluid in annular, the flow that is formed and the ability of bottom hole cleaning are highly influenced by specifications of mud pump as a resource power for mud to flow that also will determine how the value of flow rate can be circulated. Mud rheology, PV, YP and MW will influence the performance of mud to carry cutting on drilling operation. The penetration to formation rock will make the broken bits of solid material removed from a borehole drilled by bit and resulting the drill cuttings. These cuttings could settle on the bottom of borehole so the main purpose of drilling fluid is to carry the cuttings to the surface, besides the drilling fluid also protecting borehole condition from any drilling problems. This evaluation is using Power Law Model for calculate pressure losses, drilling hydraulic optimization and also observe the parameter of Cutting Transport Ratio (Ft), Cutting Concentration (Ca), Cutting Carrying Index (CCI) and Particle Bed Index (PBI). The optimization results from Bit Hydraulic Horse Power (BHHP) method produce significant changes which are percentage horse power delivered to bit (%HHP) increasing to 53.17 – 54.79 % from actual condition which only ranges 5 – 51 %. Q optimum is very influential on the value of bit hydraulic horse power (BHHP) and surface horse power (HPS) that provide more optimized power to pump the mud with minimize the effect of pressure loss.

E&P Notes (December 2019)

E&P Notes (December 2019)

E&P Notes (August 2019)

E&P Notes (August 2019)

Enhancing Drilling Parameters in Majnoon Oilfield

The objective of drilling parameters optimization in Majnoon oilfield is to arrive for a methodology that considers the past drilling data for five directional wells at 35 degree of inclination as a baseline for new wells to be drilled. Also, to predicts drilling performance by selecting the applied drilling parameters generated the highest rate of penetration (ROP) at each section. The focal point of the optimization process is to reduce drilling time and associated cost per each well. The results of this study show that the maximum ROP could not be achieved without sufficient flow rate to cool and clean the bit in clay intervals (36" and 24") hole sections. Although the influence of combination of Weight on Bit (WOB), Round per minute (RPM), and hydraulic horsepower on the bit in (16", 12 1/4" and 8 1/2") hole sections is a key to reduce drilling time, therefore, the drilling parameters produced the fastest ROP per each section was considered as optimum parameters likely to apply for the future wells.

SOLAR POWERED IRRIGATION SYSTEM FOR TURF AREA

Solar water pumping system may be a competitive application for remote and luxurious areas where power costs a lot. One may argue that solar photovoltaic water pumping systems not only comprises an environmentally friendly solution, but also contributes substantially to the satisfaction of remote communities’ water consumption needs. Therefore, the study aimed to manage pump for sprinkler irrigation system operated by solar power in small area of turf. The required hydraulic experiment and measurements were conducted using Direct-coupled photovoltaic pumping system to operating sprinkler irrigation network at the experimental farm of soil and water Research Department, Nuclear Research Center, located at Inshas, Sharkia Governorate, Atomic Energy Authority, Egypt. The essential idea to operate the sprinkler irrigation system and fulfill the water needs of turf area was to use a locally assembled pump-set to match the photovoltaic generator unsteady output. Results indicated that, solar radiation increased during summer (April and July), so the electric power, pump discharge, pressure head, Hydraulic horsepower (hp) and Photovoltaic conversion efficiency are affected as solar radiation changed. Four mathematical equations has been derived to illustrate the relationship between solar radiation and electric power, pump discharge pressure head , water hp and Photovoltaic conversion efficiency (PVCE) during the day hours.

Optimization of Hydraulic Horsepower to Predict the Rate of Penetration

The rate of penetration has an important role in the success of a drilling operation, this is because if the rate of penetration is not optimum will have an impact on the cost incurred. Some factors that influence the rate of penetration are the weight on bit, rotation per minute and horsepower. Based on the analysis obtained WOB and RPM values are optimum so that optimization is done on horsepower. In this case study the well that will be analyzed is vertical well so that bit’s hydraulic optimization is performed using Bit Hydraulic Horse Power (BHHP) method by adjusting the nozzle size and circulation rate, this method will be optimum if BHHP / HPs ratio is 65%. Evaluation on trajectory 12 ¼ well “SGT-01” field “Tranusa", obtained bit’s hydraulics on the actual conditions at 2657.48 ft - 2723.10 ft depth interval obtained Bit Hydraulic Horse Power (BHHP) of 232.67 hp, Horse Power Surface (HPs) 499.82 hp, Horse Power per Square Inches (HSI) of 1.67 hp / in² and percentage (BHHP / HPs) of 46.55% (<65%) indicating less optimum then optimized hydraulic bit circulation rate optimized to 710 gpm with Horsepower Hydraulic Horse Power (HPH) of 936.47 hp, Horse Power per Square Inches (HSI) of 5.4 hp / in² and percentage (BHHP / HPs) of 65% (already optimum). The final result of the evaluation and optimization of bit hydraulics and the removal of cutting is predicted to increase ROP from 46 fph to 125.66 fph.

Pressure Loss Estimation of Three-Phase Flow in Inclined Annuli for Underbalanced Drilling Condition using Artificial Intelligence

Underbalanced drilling as multiphase flow is done in oil drilling operation in low pressure reservoir or highly depleted mature reservoir. Correct determination of the pressure loss of three phase fluids in drilling annulus is essential in determination of hydraulic horsepower requirements during drilling operations. In this paper the pressure loss of solid-gas-liquid three-phase fluids flow in inclined annulus was estimated using artificial neural network (ANN). Experimental data which are available in the literature were used for design of ANN. Pressure loss as output of ANN, was estimated from five effective parameters as inputs of ANN including gas and liquid superficial velocities, the inclination from horizontal, rate of penetration (ROP), pipe rotation speed (RPM). The correlation coefficient between predicted and experimental value for train and test data is 0.998 and 0.997 respectively.The root mean square error (RMS) and average absolute percent relative error (AAPE) for train data are 0.0082 and 2.77% and for test data, they are 0.0108 and 3.68 % respectively. The reliable results showed the high ability of artificial neural network for estimating pressure loss of three phase flow in annulus.

Theories and Applications of Pulsed-Jet Drilling With Mechanical Specific Energy

Summary Mechanical specific energy (MSE) is the amount of energy required to destroy a unit volume of rock. The main work of this study is to bring the hydraulic energy of a pulsed jet into an MSE model and further analyze the mechanism of improving the rate of penetration (ROP) for pulsed-jet drilling on the basis of the model. Laboratory experiments are used to obtain the relationship of bit hydraulic horsepower between pulsed jet and continuous jet, and then the MSE model of pulsed-jet drilling is established. According to the MSE theory, the major mechanisms of improving ROP in pulsed-jet drilling are changing the breaking strength of rock and improvement of downhole-cuttings-cleaning efficiency. Field tests and data presented in this study showed that this model could be used to evaluate drilling efficiency and identify abnormal conditions for pulsed-jet drilling. All tests were operated with similar parameters and on the same drilled formation. The field results illuminate that pulsed-jet drilling has higher drilling efficiency compared with conventional drilling. Moreover, the specific patterns for abnormal conditions can be detected in real time in the process of pulsed-jet drilling. This model is less ambiguous as well as robust. Therefore, it could provide theoretical support for the wide application of pulsed-jet drilling.

Technology Focus: Drilling Technology (February 2014)

Technology Focus Once again, we find ourselves in a time of extreme challenges on many fronts in the arena of well construction, with corresponding needs for technological advancements. Anyone who has been around the drilling-and-completion world during the past several years can attest to the unique environment in which we operate today. Ever-increasing drilling depths and formation temperatures and pressures are combined with depletion of mature basins and unprecedented geopolitical uncertainty. The good news is that human innovation and problem solving continue to accelerate commensurate with these challenges. In this feature, we specifically highlight the persistent need for high-performance drilling fluids. Back in the early 1980s, when I started in the business, in-house “Drilling Engineering 101” courses with a major operator defined three primary objectives for a drilling fluid: (1) hydrostatic pressure for well control, (2) delivery of hydraulic horsepower to the bit, and (3) adequate rheology for hole cleaning. Of course, these criteria must still be satisfied or the ability to deliver a given well to total depth is jeopardized. However, today there is much more to consider: wellbore strengthening in low-fracture- gradient environments, special fluid systems for narrow porepressure/ fracture-gradient windows, low toxicity for safety and environmental consideration, nondamaging water-based drill-in fluids, and wide-ranging formulations for nonaqueous systems. The wealth of available SPE publications provides a fantastic resource for the vast array of drilling-fluids strategies today. With the ongoing evolution of managed-pressure drilling, companies are expanding the envelope of technical feasibility and successfully constructing wells thought to be undrillable a few years ago. Onshore US and in many other areas of the world, another revolution is taking place in the realm of directional drilling, with new tools and techniques for rotary-steerable applications, measurement/logging while drilling, and bits. These technological advancements are profoundly altering the energy outlook through horizontal and complex-directional-well design, with corresponding delivery of reserves and value. And, of course, unprecedented advancements have been made in zonal isolation, cement-slurry design, and cement-placement techniques. Starting with clearer definition of permeable zones in the planning phase, operating companies, working in partnership with third-party service providers, are demonstrating the ability to hydraulically isolate water- and hydrocarbon-bearing formations, greatly enhancing well integrity and reliability and reducing risk for the life of the well. Good news indeed for all of us. JPT Recommended additional reading at OnePetro: www.onepetro.org. SPE 163957 Practical Directional- Drilling Techniques and MWD Technology in Bakken and Upper Three Forks Formation in Williston Basin North Dakota To Improve Efficiency of Drilling and Well Productivity by Guangzhi Han, Baker Hughes, et al. SPE 166456 Newtonian Fluid in Cementing Operations in Deepwater Wells: Friend or Foe? by Polina Khalilova, Schlumberger, et al. SPE/IADC 163410 Large-Bore Expandable Liner Hangers for Offshore and Deepwater Applications Reduce Cost and Increase Reliability: GOM Case History by John McCormick, Halliburton, et al. SPE/IADC 163451 A Collaborative Approach for Planning a Drilling-With- Liner Operation by Steven M. Rosenberg, Weatherford, et al.