bluuebunny/crossref_metadata_2025_split huggingface dataset:
Test Results Field & Lab for a New Composite Perforating Method that Integrates Propellant and Shaped Charges
Authors: Albert Larry 
Published: February 2020

Abstract
A new perforating technique employing the integration of conventional shaped charges and solid propellant was described by Albert, et.al. (SPE 197185-MS). The innovative propellant deployment method allows the propellant deflagration to occur in the perforation tunnel rather than gun body and casing, thus delivering maximum energy to improve perforation tunnel performance. Shaped charges utilizing high energy explosives perforate casing and formation with high speed metallic jets that displace by sheer force. The explosive events are fast (20-30 microseconds) high impact events (as high as 1.5 million psi at the rock face) that can collapse large pores in the formation along the surface of the perforation tunnel. This crushing along the tunnel reduces permeability and increases skin and can impact the flow of fluids into and out of the reservoir rock. A number of methods have been developed to improve perforation tunnel flow efficiency, but all suffered limits on either deployment or effectiveness.
Propellants have been used for decades to improve perforation performance. Propellants are energetic materials with slower burn rates that can micro-fracture the formation and break-up the crushed zone around perforation tunnels. Prior methods deflagrated the propellant materials within the gun bodies, or casing and lost a significant amount of energy before delivering impact to the perforation tunnel. The new method with a composite cap of solid propellant on the face of the shaped charge, displaces the propellant into the perforation tunnel before deflagration, thus delivering maximum energy to the formation. This helps break up the crushed zone and micro-fracture the formation.
The improved perforation tunnel will reduce frac fluid tortuosity. Frac jobs can get better fracture initiation and better proppant placement, resulting in better production. This paper will focus on additional lab testing at an Advanced Perforating Flow Laboratory plus several USA onshore completions (horizontal and vertical). The field data will show the effect of the composite perforation method on frac performance and well production.
Successful Application Analysis of Double Water Control in Fractured Reef Reservoir in Liuhua Oilfield
Authors: Luo Donghong , Dai Zong , Wang Yahui , Pei Bailin , Wang Hailong , Shen Zheng , Zhu Hongxia 
Published: February 2020

Abstract
Water breakthrough (WBT) in the horizontal wells often leads to water flooding in the well, especially to those heavy oil reservoirs in reef limestone carbonate. The excessive water production from the hydrocarbon producing horizontal wells can adversely affect the economic life of the well, furthermore this could result in the well permanent abandonment. Nowadays, no effective methods of water control are available for the similar reservoirs, traditional water control methods have three technology barriers: (1) can not accurately locate the WBT positions;(2) difficulty of identifying the wellbore completion, fluid, and nearby formation conditions;(3) Not being designed to control water from new water breakthrough points.
This paper shows a newly developed water control technology by using continuous Packed-off double water control technology (CPI). It was successfully implemented in a well of a fractured reef limestone oil field in South China Sea. This technology completely overcome the above shortcomings of traditional water control methods. The mechanism is to pack patent particles into the wellbore and near-wellbore fractures to create a double "artificial well wall". It suppresses radial and axial turbulence effectively. The operation procedure of CPI water control method is simple. It has been proven with lower cost and longer effective duration of controlling water, which can greatly increase oil recovery.
Results show that the water content in the well of CPI water control is only 10% to 33% of the adjacent wells at the same geological layers. The initial oil water ratio in the CPI well is 13, which is ten times better than the adjacent wells. After 2 months' production, the water content of CPI well is 13.3%, compared to 67%, 62%, and 89% of the adjacent wells.
Digital Oilfield: Review of Real-time Data-flow Architecture for Upstream Oil and Gas Rigs
Authors: Sletcha Ben , Vivas Cesar , K. Saleh Fatemeh , Ghalambor Ali , Salehi Saeed 
Published: February 2020

Abstract
Advances in horizontal drilling and completion techniques have proliferated onshore development of unconventional shale fields. These wells can span hundreds of miles across a field for a single operator. Live remote monitoring and automation of operations is ideal but rarely cost-effective.
Upstream oil and gas operations face many challenges measuring and sending data from remote well sites. Sensors must operate in remote areas, challenging terrain, and inhospitable environments, making very difficult to implement a wireless data flow collection and transmission. Additionally, data integration and consolidation between many devices, software packages, file sizes, and file types, compounds the challenges for analyzing the data for potential improvements in operational efficiencies.
Autonomous remote measurement, transmission, and control of oilfield sensors continuously pursued, but rarely fully implemented. The fast production decline of unconventional shales makes high-cost telemetry systems perceived as not economic to install within a few years after the initial production of a well. However, Oil and Gas industry sensors are improving in reliability and become more robust to work in harsh environments. The transmission networks have increased their capabilities and coverage, representing the evolution of every component that conforms the onshore oilfield data architecture, becoming their implementation easier than the recent past.
This paper describes the real-time data-flow architecture for oil and gas well operations, and what are the main challenges of implementing the digital oilfield concept by studying the actual use of devices in the field and the conditions in which they operate for understanding the digital oilfield implementation challenges. Also, there are presented some examples of how the industry is benefiting from real-time data-flow architecture and a brief introduction of how it can be connected with big data implementation for enhancing oilfield operations.
A Novel Approach to Salvaging Well Completions with Mud Damage using a Specialized Fluid System; The First Cases in Nigeria
Authors: Ogbunuju Emi , Okolomma Emmanuel , Ibrahim Yahaya , Imbazi Onyeintonbra , Ukpe Uduak , Burts Donnie , Justus Charlie 
Published: February 2020

Abstract
Well re-entry necessary to wash/cleanup suspected barites and barium sulfate residues in two wells located onshore Niger Delta, Wells AA & BB drilled and completed to develop a cumulative of over 700 Bscf of gas and 30MMstb of associated condensate reserves at an initial cumulative potential of 240 MMscf/d, producing below par at about 15% planned daily production.
The sand face for these Single String Gas Producers were drilled with 13.8ppg POBM. Post well completion, hookup and initial cleanup, the wells were suspected to have remained suspended with drilling and completion debris also, various HUD's were encountered within completion string.
Previous reentries proved rather unsuccessful for the operator as these wells could not be cleaned up even after using 3 different traditional stimulation fluids pumped in high volumes. As a result of the challenges experienced during the previous interventions, the operator sought a different approach which included the deployment of a specialized stimulation treatment, which is a mixture of organic acids, solvents and clay inhibitors with built in corrosion sequestration and de-emulsifiers via CT.
This specialized two-fluid treatment comprising of pre-flush and main treatment was sequentially pumped and allowed to soak for 5hrs and 36hrs respectively.
CT run planned to be performed with a jetting tool run across the SAS was not feasible as there was no access to the bottom of the SAS assembly as several attempts to mill out the HUD encountered in the tubing string proved abortive.
This paper aims at presenting advances in barite dissolving capability with non-damaging stimulation fluid and powerful "descaler" which although reacts quicker in warm environments (&gt;100°F), is not largely temperature dependent to reach depletion with normal reactions taking place within 24hours. The post stimulation results and recovered debris validates the dissolving capabilities for cleaning sulphates of barium, strontium and calcium as well as calcite in wellbores.
Formation Damage Control, Modeling, Analysis and Remediation Techniques
Authors: Al-Qasim Abdulaziz , Almudairis Fahad 
Published: February 2020

Abstract
Formation damage can occur in the vicinity of the wellbore or far field in the reservoir. Organic and inorganic deposition such as asphaltene, paraffin, iron sulfide, barium sulfate and calcium carbonate are the most commonly encountered scale types of damage. Accidental interactions between the completion kill fluid after the perforation or the drilling fluid while drilling through the target zone are also major causes. The decline of well productivity is the first indication of formation damage and can be used as a determining factor of its severity. Therefore, the type of damage, the mechanisms, and controls need to be analyzed and predicted.
This paper presents a detailed and comprehensive review of formation damage including both the external and internal types and the far field and near-wellbore damage. Damage can be identified by observing changes mainly in the well productivity; however, it can be also observed using retrieved equipment such as logging tools and downhole pumps or due to the restricted entry of completion equipment such as inflow control devices (ICDs). The impact of well configuration on the formation damage and the remedy afterwards is also discussed in details.
The present study provides a solution and control criteria for the formation damage and a comprehensive mechanistic modeling is proposed. The model is applied by coupling reservoir modeling with the wellbore conservation equations through the pressure. The effect of horizontal laterals is included by developing three-phase transient equations to account for the flow rate change from toe to heel in the drain hole.
Gas Production Enhancement by Polymer Treatment
Authors: Zaitoun Alain , Templier Arnaud , Hernando Louis 
Published: February 2020

Abstract
Many gas wells in Adriatic Sea are suffering from both water and sand production. An original sand control polymer technology has been successfully implemented and has proven to be an efficient way to stop sand production and thus maintain gas well under steady production. In many wells, a reduction of water production was observed as side effect. Nevertheless, the main objective remained sand control and not water control.
The present paper describes a polymer treatment performed in an offshore well equipped with sand control gravel-pack downhole completion. This well was suffering of high level of water production inducing a severe decline in gas production. The preparation of the treatment consisted of lab coreflood tests aiming at checking the behavior of the selected polymer (P-321) in actual reservoir conditions. The product was shown to have good injectivity and to strongly adsorb on the reservoir rock. Moreover, it has good RPM properties, inducing a strong reduction in water relative permeability while preserving gas relative permeability.
The treatment proceeded in the bullhead mode, i.e. through the gravel pack. The polymer was followed by a Nitrogen postflush to squeeze the product deep in the formation and help restarting the well. Immediately after treatment, gas rate increased while water rate levelled off. Both gas rate and GWR (Gas Water Ratio) stopped declining and remained at same level for two years. After two years, the estimated additional gas production was 13,330 KSCM and the well keeps flowing steadily instead to be probably shut in if it had followed its initial decline trend.
Reinforcement of Polyacrylamide-Co-Tert-Butyl Acrylate Base Gel Using Nanosilica for Conformance Control at Low and High Reservoir Temperatures
Authors: Shamlooh Mohamed , Hamza Ahmed , A. Hussein Ibnelwaleed , S. Nasser Mustafa , Salehi Saeed 
Published: February 2020

Abstract
Challenges of water shut-off, which is categorized under conformance control, are nowadays common in the oil and gas industry. The excessive water quantities produced from oil reservoirs can make the production process economically infeasible. The target of water shut-off process is plugging fractures or high permeability zones to decrease water cuts. Polyacrylamide tert-butyle Acrylate (PAtBA) is used for such applications. Silica (silicon dioxide) has been found to have a strengthening effect as well as it enhances the thermal and mechanical stability of the system. The objective of this study is to introduce nanosilica to reinforce PAtBA crosslinked by polyethyleneimine (PEI) and chromium Acetate (CrAc3) for low and high temperature conformance control applications. In this study, different ratios of polymer to crosslinker were investigated to choose the optimum combination. Then, nanosilica (NS) with different sizes (20, 50 and 85 nm) was added to the polymeric formulation with the inorganic crosslinker (CrAc3) to study the effect of silica content and size on gel strength. While, the reinforcement of the organically crosslinked gels with PEI was accomplished at 130°C. Evaluation of different systems was based on testing the rheological behavior of the mature gel based on the final storage modulus (G′). Differential scanning calorimeter (DSC) technique was also employed to understand the nature of chemical interaction between the various chemicals. The investigation reveals that PatBA:CrAc3 of 9:0.5 is the optimum ratio producing the most strong gel. Silica with the size of 20 nm has produced the strongest gel by increasing the storage modulus by more than 150 %. At high temperature (130°C), 50 nm silica with PAtBA/PEI showed the highest storage modules compared to other sizes. DSC investigation discloses that silica is an inert and has no effect on the gelation reactions. Thus, silica has physical interactions with the polymer in the form of hydrogen bonding which enhances the strength of the gel in comparison with silica-free gels. Therefore, this study introduces a new polymeric formulation that serves as a water shut-off agent for reservoirs at low and high temperatures. The formulation that consists of PAtBA, CrAc3 and NS makes the system more stable and gives it more resistivity toward high shears. Whereas higher gel strength was achieved when PAtBA/PEI/NS was used at high temperatures.
First Open Hole Gravel Pack with AICD in Ultra Deep Water
Authors: Pedroso Carlos Alberto , Latini Carolina , Araujo Zaque , Garcia Peterson , Soares Robson 
Published: February 2020

Abstract
The execution of Open Hole Horizontal Gravel Packs (OHHGP) in ultra-deep waters (greater than 1500m) demands the use of the best technologies available. For the Atlanta Project, a detailed description of the first two wells successfully completed with OHHGP in the field, was provided in previous papers (OTC-25813, SPE-174893, SPE-174896). The third Atlanta well faced a new challenge: the integration of AICD technology (Autonomous Inflow Control Device) in the gravel pack screens.
Due to the restriction imposed to the flow through the screens by the AICDs, the resulting pumping pressure and associated ECD (Equivalent Circulating Density) is increased, further reducing the already narrow operational window, which is common for reservoirs in such water depths. The use of AICD technology, which imposes an additional pressure drop to the aqueous fluid flow, further increases the pumping pressure, making conventional gravel packing strategies and procedures unfeasible.
To overcome these new challenges, dozens of simulations were performed to address the new challenge and an innovative screen configuration was adopted to facilitate effective gravel pack placement while retaining the necessary fluid flow restriction of the AICD operating as per the simulation design during well production. Additionally, to ensure effective and complete gravel pack efficiency, a new pumping procedure, incorporating the use of three different proppant strategies, was implemented.
By introducing these innovations, the third Atlanta well was 100% packed and the expected PI was obtained. Long-term performance, with the aid of tracers installed in the screens, is being evaluated.
This paper will detail all the planning and execution phases that enabled completion of the first open hole gravel pack with AWES RP T2 AICDs in ultra-deep waters. Also in this paper, the production evaluation data is analyzed.
Using Particle Size Theories to Optimize Bridging Solids for Post-Gravel-Pack Screens
Authors: Abiodun S. , Vincent J. M. , Schultz K. , Rapp E. 
Published: February 2020

Abstract
A simple and effective particle-size selection program was developed to significantly reduce the amount of testing required when designing bridging solids systems for use in fluid loss control pills for gravel-pack or frac-pack applications. Applying Ideal Packing Theory (also known as the D½ rule) and Abram's 1/3 rule with some modifications, linear plots of cumulative volume percentage of bridging particles versus the square-root of particle diameter was used to obtain optimal formulations of bridging solids in ratios that effectively bridged and sealed machined, laboratory-grade, wire-wrapped screens of 2.5-inch. o.d., 2-inch i.d., and 0.25-inch thickness.
High-pressure/high-temperature (HP/HT) filtration testing of optimized screen-specific formulations of calcium bromide-based TETRA SmartSeal™ pills was completed using 6, 8, 10 and 12 gauge screens under 500 psi pressure and 215°F temperature conditions over a 72-hour period.
The results show that low-permeability, well-packed filter cakes of thickness less than 2 mm were formed on the screens, allowing minimal fluid passage, with average spurt volume less than 6 mL, average 30-minute filtrate volume less than 8 mL, and maximum 72-hour filtrate volume less than 25 mL.
Our Choice: study protocol for a randomized controlled trial for optimal implementation of psoriasis treatment by the integration of Chinese and Western Medicine
Authors: Sun Xiaoying , Zhou Xiaoyong , Wei Yuegang , Yang Wenxin , Huang Ning , Ding Yangfeng , Hu Rongyi , Guo Shun , Yang Chunyan , Weng Huilan , Zhang Ying , Chen Xi , Ding Xiaojie , Liu Liu , Yin Qingfeng , Wang Ruiping , Li Xin , Li Bin 
Published: February 2020

Abstract
Background: Plaque psoriasis is a refractory inflammatory skin disease. The common therapies used to treat plaque psoriasis in traditional Chinese medicine (TCM) and Western medicine (WM) therapies have distinct characteristics and advantages. Although a combination of TCM and WM therapies, adjusted to the clinical situation, is widely used; there are no systematic studies on the hierarchical selection of this treatment combination, based on the severity of skin lesions. We therefore designed a randomized clinical trial to focus on the sequence of internal and external treatments of TCM in patients with mild to moderate plaque psoriasis and to optimize the integration of Chinese and Western medicine for the treatment of patients with severe plaque psoriasis, thereby achieving high-level clinical evidence and establish treatment norms for the integrated use of Chinese and Western medicines. Methods: In this proposed multi-center, single-blinded, randomized, controlled trial, 108 patients, with mild-to-moderate plaque psoriasis, will be randomly assigned to two groups in a 1:1 ratio to receive either internal or external TCM treatment and 270 patients, with severe plaque psoriasis, will be randomly assigned to three groups in a 1:1:1 ratio to receive treatment with TCM or WM, or TCM+WM. All enrolled patients will receive 8 weeks of treatment. Follow-up assessments will be done 8 weeks after the treatment. The primary outcome of this study is the evaluation of efficacy and relapse rate, based on the psoriasis area and severity index, and the secondary outcome measures include determination of the affected body surface area, physician’s global assessment, pruritus scores (determined using a visual analogue scale), TCM symptom score, dermatology life quality index, patient-reported quality of life score, and incidence of serious adverse events. Discussion: This study will provide a high-level clinical evidence for internal and external TCM treatment optimization and will contribute to establishing norms for the integration of Chinese and Western Medicines.
Intention to quit water pipe smoking among Iranian women: A qualitative directed content analysis
Authors: sabzmakan leila , Eslami Fatemeh , Sighaldeh Shirin Shahbazi , Izuka Nkeonye Judith 
Published: February 2020

Abstract
Background: Water-pipe smoking is the most common type of tobacco used among Iranian women. The aim of this study was to explain women’s perceptions of their intention for quitting water-pipe smoking based on the theory of planned behavior.Methods: The study was a qualitative content analysis which was carried out over four months in 2016 in Tehran-Iran. The participants were 26 women ages 18 to 45-years-old who smoked water-pipe and were selected through snowball sampling. The study was performed in hookah cafes, parks, and homes. The data were collected through individual interviews. The interviews were open-ended questions based on the theory of planned behavior. Directed content analysis was used to analyze the data. Results: Findings showed that the women did not intend to quit water-pipe in that time. Main contributing factors influencing not having intention of cessation were positive attitude and false beliefs toward hookah smoking, as well as having peers and family members who smoked WP or approved its use. Although most females realized the obstacles associated with hookah cessation, they believed that quitting WP smoking was up to themselves and could control more barriers.Conclusion: Social pressure, positive attitude and false beliefs towards hookah smoking, as well as external and internal obstacles diminished women ‘s intention for cessation. Therefore, it is recommended to apply the theory of planned behavior into behavior change interventions in order to increase the intention to quit water-pipe smoking.