bluuebunny/crossref_metadata_2025_split huggingface dataset:
Effect of Drilling Fluid on Rock Mechanical Properties at Near-Drilling Conditions: An Implication of Fluid Design on Wellbore Stability
Authors: Yadav Prahlad Kumar , Ali Syed Shujath , Tawat Najeeb Ahmed Al , Dhamen Ali Abdullah Al , Jin Guodong 
Published: March 2016

Abstract
Selecting a drilling fluid from the learnings from conventional reservoirs can be a wrong choice when it is used for unconventional formations. Drilling fluid has a chemo-mechanical effect on the reservoir rock during exposure time; this interaction can be abrupt or imperceptible depending on minerals comprising the rock matrix and their chemical sensitivity to the fluid composition. Improper selection of drilling fluid may cause strong shale-fluid interaction and thus result in wellbore instability. This paper presents a comprehensive experimental study examining the effect of various drilling fluids on the mechanical properties of conventional and unconventional rock samples.
Four drilling fluids with varying additives are selected to contact and saturate rock samples at the temperature of 230°F for 16 or 24 hours: Three of them are water-based muds (WBM) and the other one is an oil-based mud (OBM). Rock samples used are from the Berea sandstone, Mancos and Eagle Ford shale formations. For each type of rock, one plug is tested without contacting any drilling fluid and is used as a reference of geomechanical properties. Other samples are contacted and saturated with other drilling fluids before their geomechanical testing. A fluid-saturating process is conducted at a pressurized aging cell. Mechanical testing is performed in a servo-controlled triaxial apparatus in which samples are deformed at a constant confining pressure of 10 MPa and the drained condition.
Experimental results show that drilling fluids have a negligible effect on the peak strength and Young's moduli of Berea sandstone. However, the peak strength of Mancos shales decreases dramatically while their Young's moduli change randomly. For Eagle Ford shales, fluids reduce both peak strength and Young's moduli. For all samples tested, their Poisson's ratios increase after samples are saturated with fluids. Compared to WBM, it is observed that OBM preserves the mechanical properties of Mancos shales much better. After optimizing the design of one high-performance water-based mud (HPWBM1), the new fluid (HPWBM2) has an improved performance (similar to OBM) in preserving shale geomechanical properties.
Comparative Study of Gas to Liquids (GTL) Technology for Monetising Marginal Reserves and Wasted Flared Gas
Authors: Menon Manu 
Published: March 2016

Abstract
This paper provides a comparative study between gas to liquids (GTL) technologies that are targeted at capturing stranded and associated gas. As a result, it should act as a preliminary guide to oil and gas operators who intend to gain an overview of available miniaturised technologies. Subsequently, this would assist operators with decision making regarding potential monetization of stranded and associated gas available in their oilfields. The miniaturised GTL technologies will be compared by collating data published from the companies' website, online publications and journals as well as correspondence between the author and company representatives. The paper examines intrinsic differences between the fundamental chemistry between technologies used to produce synthesis gas in terms of steam methane reforming, autothermal reforming and partial oxidation. Figures shall be used to compare the maturity and commercial readiness of technologies provided by GTL companies. Maturity and commercial readiness will be based on the availability of a pilot plant showcase and activity of the companies in presenting their technology at oil and gas conferences. In addition, the status of the respective companies and their current affiliates will be described. In summary, this paper provides a list of players in the GTL atmosphere who are actively seeking to innovate the GTL process to make it feasible to handle stranded and associated gas; i.e. monetizing small volumes of gas that would otherwise be overlooked or flared.
Combination of Innovative Multi Zone Single Trip Gravel Pack System Aids Cutting Completion Cost in Mahakam Block
Authors: Muryanto B. , Wahyudhi F. , Caillon D. , Styward B. , Sinaga H. A. , Wijaya R. , Risatrio A. A. , Anashkin A. , Jatikusuma R. , Maharanoe M. I. 
Published: March 2016

Abstract
More than 1000 gravel pack zones have been completed using Multi Zone Single Trip Gravel Pack (MZ-STGP) system in Mahakam block, East Kalimantan, Indonesia. The system has been proven to be cost effective solution to produce multi layered sand prone reservoirs. The current challenge is to further cutting completion cost to produce marginal reservoirs which can not be produced even using already established MZ-STGP.
Three areas of improvement are explored based on database of more than 250 wells. The first one is reducing gravel pack pumping operation time. The second option is to extend total gross length of MZ-STGP to complete more reservoirs. Another improvement to be looked at is to replace Gravel Pack (GP) with alternative sand control solution.
Using innovative design of shunt tube, MZ-STGP wells can be completed with more than 700 m gross interval and simultaneously pumping several zones. At the same time, extensive optimizations have been done to extend length coverage of MZ-STGP. One of the improvements is by using fit for purpose single string design. The other alternative is to use alternative sand control methods. Encouraging results were gathered from initial production test from pilot wells. To date, four wells were completed with ceramic screen completion and one well with shaped memory polymer.
The success of initial pilot gives a good base for improving and confirming reduction of completion cost. Industrialization of combined solutions may lead to access to reservoirs previously considered as non economical.
Optimization of Shutdown Valve Weight and Size
Authors: Nair Suresh 
Published: March 2016

Abstract
Automatic Shutdown Valve also referred to as, Actuated Shutdown Valve is designed for automated protection to safeguard personnel, environment and to control hazardous or abnormal operations.
Ball valves are widely used for Shutdown service, fitted with quarter turn actuator. Pneumatic Scotch-Yoke type is the preferred actuator design with single acting and spring return type configurations to meet fail-safe conditions and safety critical functions.
The article stated hereby as Shutdown Valve is a general term used for the complete assembly inclusive of Valve coupled with Actuator for shutdown service. Optimization of the assembly is examined in this article through significiant emphasis on the coupled automatic actuator.
Through marginal changes in the pneumatic system design and usage of appropriate variable factors in actuator torque profile, aims to evaluate optimization techniques for shutdown valve actuator weight and size / dimensions.
An analysis on actuator weight and size affected through actuator design factor is carried out in this article. The details are extended to actuator sizing data, illustrations and comparisons, to outline the approaches currently followed and the possible area of improvement in the pneumatic design and actuator selection.
The paper assesses the advantages on actuators types and the variance between design methods. In addition, the article analyses the air supply to actuator and feasibility for the improvement in design.
Challenges Associated with Developing Foamers for Subsea Producing Fields with Glycol Regeneration
Authors: Suandi Lizman Mat , McRae Alex 
Published: March 2016

Abstract
This paper describes the challenges associated with chemical treatment of liquid loaded, gas condensate in subsea pipelines and the importance, of not only performance but also stability in glycol regeneration processes downstream. Untreated field produced fluids were used in all foamer production formulation and testing. Standard column sparged testing was used as initial screening, followed by a modified method to mimic the response to increase in dosage and concentration of chemical in the fluids to be unloaded. The product was designed to be compatible with capillary string for subsea injection, and with the glycol carrier fluids that it would be injected with. It also had to be thermally stable to withstand the glycol regeneration process that the fluids passed through on the topside process after the pipeline reaches surface. Product formulation on field fluids resulted in a chemical foamer that resulted in thick foam but with quick collapse time and half-life, which limits any possible carry over into the production process. The product was found to be thermally stable at 170°C and would not cause any contamination of the glycol regeneration process. Production application in the field is expected in second quarter of 2016, and all results will be shared in this paper. Product was formulated with blend of sulphonated quaternary ammonium compounds and polymers, in conjunction with high boiling point glycols to withstand high temperatures and function as good foaming agents in mixed water/hydrocarbon systems.
Reduce Project and Life Cycle Cost with TCP Flowline
Authors: Steuten Bart , Onna Martin van 
Published: March 2016

Abstract
Thermoplastic Composite Pipe (TCP) is a spoolable, fully bonded, thermoplastic pipe with glass or carbon fibre reinforcements. The bonded composite pipe has a solid wall, like steel pipe and is able to cope with corrosive environments without being affected. For its lightweight and collapse resistance, TCP is most often associated with deep water. However, it is the combination of the solid wall, spoolability and no corrosion what makes TCP very attractive for production flowline applications, also in shallow water.
Leading TCP manufacturer Airborne Oil & Gas has qualified TCP for a number of applications and companies and has successfully delivered multiple TCP projects. In support of the market implementation, and as a the result of a broad industry JIP with participation of 19 companies, DNVGL has issued a Recommended Practice for Flexible Thermoplastic Composite Pipe. Furthermore, API has established a committee to draft a recommended practice for bonded composite pipe for offshore applications, API 17Z.
The spoolability and the ability to manufacture TCP in long lengths reduces installation cost significantly. This paper describes a shallow water reel laying installation method for TCP and compares the typical project scope with other pipeline options. With corrosion being a major cost driver for operational cost, thanks to the lack of corrosion of TCP, the operational cost for the operator are also reduced significantly in comparison to rigid steel pipe.
Reducing both installation and operational cost offsets the higher material cost for TCP compared to steel pipe and results in a total reduced life-cycle cost of the flowline.
Concept Stage Site Assessments, Deepwater Development Risks, and Long-Term Value Preservation: Why Getting it Right the First Time is More Important Than Ever
Authors: Haneberg William C. , Campbell Kerry J. , Mackenzie Brian 
Published: March 2016

AbstractConcept stage site assessments based on exploration 3D seismic data and other existing information are critical elements in the deepwater field development sequence. Such assessments help create value by defining site conditions and geohazards that may eventually constrain development, which in turn allows risks to be properly evaluated before significant development decisions are made. Several decades of deepwater development consulting experience, however, have shown that—despite their great value—concept stage site assessments are often not undertaken because 1) decision makers do not know that the assessments should or could be performed, or 2) there is a misconception that money can be saved by skipping steps or executing steps out of sequence in order to fast-track a development. As shown by way of two examples, decisions not to perform concept stage site assessments—even in cases where the necessary data are already available and free of additional cost—can be expensive mistakes that result in project delays if surveys have to be repeated or field layouts changed. In other words, human decision makers become significant and—unlike those associated with geohazards—largely indefinable elements of risk if short-term savings accrued by doing it wrong the first time are prioritized while the potentially more significant costs of having to do it right the second time are marginalized.
The Vertical Tension Anode System: A Cost-Effective Option for Fixed Offshore Platform Cathodic Protection Life Extensions
Authors: Carpenter Ben , Nomanbhoy Juzer 
Published: March 2016

Abstract
The Vertical Tension Anode System (VTA) is an Impressed Current Cathodic Protection (ICCP) system that can be installed without divers or ROV equipment. It is a cost-effective option for the life extension of brown field offshore structures whose original aluminum anodes are depleted. In June of 2013 four large offshore platforms in the Gulf of Mexico, all with low cathodic protection potentials due to depleted aluminum anodes, had VTA systems installed in a single, continuous construction schedule. These structures were in water depths between 68 and 80 meters (225 and 262 feet), with an average cathodic protection current requirement of 1000 amps. Total installation time was only twenty-three days, which included loading, mobilization to each structure, and offloading at the end of the job. Each platform required two VTAs, thus less than three days per VTA was required. A topside crew of 10 men, an inspector, and an experienced VTA installation technician made up the installation crew. The equipment included just a few air winches, a large air compressor, a welding machine, special VTA deployment spool racks, and miscellaneous hand tools. Since the entire system was installed from topside the client was provided great savings over sled type impressed current installations or aluminum anode type systems.
Wave Seed Selection on Irregular Wave Analyses and the Max Extreme Time Windows from 3 Hours Simulations
Authors: Suwarno Gunawan , Lee Choon Hua 
Published: March 2016

Abstract
The recent trends in pipeline installation analyses are using irregular wave spectra because it produces more realistic results, especially when fatigue analyses are required. Although, by adopting irregular wave model analyses will consume more time to produce results than regular wave model. However, with current available computing technology, the required computing time is just becoming lesser and no longer a limitation issue.
Irregular Wave Analyses will require Wave realization which relies on wave Seeds selection. Wave Seed is a random number where every seed number will give different maximum wave rise, maximum wave fall and also the time windows when the peak is occurred in the 3hrs simulations.
The key question is about, How to choose the "correct" wave Seed number? There are few suggestions to address this subject. It is either to pick up several seeds randomly, and choose the average of those results; or choose several random Seeds, up to 20 seeds in fitting those results to Gumbel Distribution to get the extreme maxima, or fitting those results to Weibull distribution to compute the extreme maxima.
This paper will discuss about the effect of wave seed selection base on irregular wave analyses (i.e. maximum wave extreme rise and fall), vessel motions (i.e. Maximum/Minimum Vessel heave, Pitch, Roll at Motion, velocity and acceleration) and also during Pipeline installation analyses. The result discussion is focused on J-lay Installation analyses using reel-lay vessel. On each of the analyses (Wave, Motions and Pipeline Installation) 3hrs simulation is carried out. In the conclusion, Time windows from the motion analyses and Installation Analyses will be compared to show which motion characteristic will influence the Pipelay parameters the most. And based on those time windows, Short simulation analyses will be performed to verify the accuracy of the selected time windows.
Novel Use of Resin Technology for Offshore Pilot Hole Abandonment
Authors: Pardeshi M. , Wilke A. , Jones P. J. , Gillies J. , Jedlitschka V. 
Published: March 2016

Abstract
An operator in the Taranaki Basin, offshore New Zealand, employed resin sealant technology in a recent shelf development to isolate the vertical pilot hole from the production formations. This paper details the success of the operation in which the resin sealant was placed in the pilot hole through the drilling bottomhole assembly (BHA) by using a pump and pull technique without needing to trip out to change the BHA, resulting in time and cost savings.
The operator drilled a pilot hole to gather petrophysical data to assess the geological model and formation pressures of the field. Afterward, the pilot hole was to be permanently abandoned, blocking any flow between the pilot hole and the horizontal production wellbore. Conventional practice would be to pull the drilling BHA to surface and then trip in with a dedicated cementing work string to abandon the pilot hole with a series of cement plugs. In this case, abandonment was executed by placing resin sealant in the pilot hole through the drilling BHA without tripping out and changing the BHA.
The dynamic tools on the BHA were unaffected by the resin and drilling continued without incident. When the BHA was pulled out and examined, there was no evidence of the resin within the drilling/placement BHA string. The operator commenced drilling in the main wellbore, and set a 9 5/8-in casing at 3055 m measured depth (MD). The well has since been completed, and the lack of any observed pressure in the production string annulus indicates that full isolation was achieved in both the pilot and main production wellbores. This approach has since been adopted by the operator as the standard procedure for the remainder of the wells in the program.
Using resin technology to abandon a pilot hole through the drilling BHA allowed the operator to avoid tripping in with a dedicated cementing work string, resulting in reduction of both time and overall cost.
Safe LNG Loading of Conventional LNG Carriers in Severe Open Sea Environments
Authors: Paquet S. , Lamourette C. , Auburtin E. , Hellesmark S. B. , Thorsen T. B. 
Published: March 2016

Abstract
FLNG (Floating Liquefied Natural Gas) as a means of monetizing offshore gas is now a reality with Technip being involved in the first two major projects. Both these projects incorporate side-by-side offloading of LNG from the FLNG to the LNGC (LNG Carrier) using loading arm technology. As FLNGs move into more severe environments, the side-by-side operation is no longer applicable and a solution providing greater environmental thresholds is required. Several tandem LNG offloading systems are proposed by the industry. They provide great safety separation distance between the vessels and high environmental thresholds, but they require the use of a dedicated LNGC fleet with Bow Loading Systems or the deployment of at least three floating LNG flexible lines of sufficient length, more than 300 meters, to reach the midship manifold of conventional LNGCs.
Since early 2015, Technip has worked with HiLoad LNG AS to develop a LNG loading system that combines the advantages of tandem stern-to-bow and side-by-side offloading solutions. The system is based on already proven or qualified technologies, allows a vessel separation greater than 100 m, high environmental thresholds and minimum length of LNG transfer lines without any modification to the LNGC. The system uses the HiLoad LNG DP (dynamically positioned) vessel for the position keeping of the LNGC parallel to the FLNG and Technip's cryogenic flexible pipes for the transfer of LNG and vapor.
The main focus areas in the studies have been the risk assessment of the parallel loading configuration and the assessment of the DP station keeping capabilities within predefined operating sectors, with the system being exposed to both steady and dynamic/changing environmental conditions. Black-out scenarios have also been investigated as part of the simulation work. The HiLoad DP system was able to keep the LNGC inside a tight operating ‘green' envelope during all investigated challenging metocean conditions. The HiLoad LNG Parallel Loading System has been concluded as a feasible, well suited solution, enabling a safe and robust LNG loading method with use of conventional LNGCs.
Active Heated Pipe Technologies for Field Development Optimisation
Authors: Louvet E , Giraudbit S. , Seguin B. , Sathananthan R. 
Published: March 2016

AbstractActive heated pipe technologies are enabling solutions for field developments allowing cost effective management of flow assurance to overcome specific challenges like longer distance tie-backs and greater water depths.This paper introduces wax and hydrate issues and conventional approaches to manage them. It highlights the need for other approaches, such as active heating technologies, to reach longer tie-back distances and greater water depths.It reviews Direct Electrical Heating (DEH), Electrically Heat-Traced Flowline (EHTF), and active heated flowline bundles comprising Hot Water Circulation (HWC) and EHTF in bundle. A general presentation of these systems is given, including design, fabrication and installation methods, as well as the maturity of the technology. Typical field architecture is proposed to illustrate the benefits of each active heating technology in terms of field development optimisation.This paper provides global information and an understanding of different available solutions for active heating pipeline systems, with technical and economic perspectives, and concludes with elements for selection of optimised field architecture.Wet DEH is a field proven technology with large track record that has already been installed on a 43km pipeline in 1070m water depth. It fits production fields not requiring high thermal insulation performances and thus allowing wet insulated pipe (U-Value =2W/m2.K). The system presents high electrical power requirement (50-150W/m). Therefore, infrastructure capacities in terms of footprint and power supply available have to be checked against specific project power requirements.EHTF fits production fields requiring high thermal insulation performance provided by Pipe-in-pipe (down to U-Value &lt; 0.5W/m2.K). Thanks to its high efficiency, the system has low power requirement (typically below 50W/m). Therefore, it can also be an alternative to DEH when topsides capacities cannot meet footprint and power supply requirements. Pipeline heat tracing is a known technology for onshore plants and by extension applicable for subsea applications. The implementation of EHTF is completing qualification of this technology for deepwater applications.HWC within bundle is a field proven technology. It fits production fields requiring high thermal insulation performance provided by bundle arrangement (down to U-Value &lt; 0.5W/m2.K). The technology requires power and equipment to heat water thus impacting topsides space. These requirements vary considering project specific needs and selection of direct or indirect heating. For example, re-use of the produced water as an indirect heating medium can highly limit required power generation.