bluuebunny/crossref_metadata_2025_split huggingface dataset:
Successful Mechanical Removal of Barium Sulfate Tubular Scale by Coiled Tubing: A Gulf of Mexico Case History of an Engineered Approach for Offshore Rigless Interventions
Authors: Sopngwi Jean-Jose S. , Gauthreaux Alex , Kiburz Daniel E. , Sonnier Baine , Moghalu David , Smith Steve K. 
Published: June 2014

Abstract
Discovered in 1991 and located approximately 130 miles south of New Orleans, the Ewing Bank 873 (EW 873) field is an offshore mature field in the Gulf of Mexico that produces hydrocarbon from unconsolidated sandstone reservoirs of Middle-Upper Pliocene age. Most wells within the field were completed using cased-hole gravel packed completions, and field production began in 1994.
Throughout the production cycle of the EW 873 field, wells such as Well A-04 had experienced severe production impairment from near-wellbore (NWB) formation damage, as well as tubular buildups from barium sulfate (BaSO4) scale caused by incompatible mixing between formation water and biocide inhibited seawater that broke through from an offset injection well. While mechanical techniques such as coiled tubing-conveyed hydroblasting have been commonly used to remove BaSO4 tubular scale, the success of these techniques largely depends on the nature and magnitude of the BaSO4, as well as effective operational planning.
This paper presents the five-step engineered approach of the coiled tubing hydroblasting intervention that mechanically removed as much as 3,150 ft. measured depth (MD) of BaSO4 tubular scale from Well A-04. Additionally, the paper presents the tools that were utilized throughout the intervention and the laboratory and field methods that were applied to characterize the BaSO4. With NWB formation damage and production impairment already established to be a problem on Well A-04, the successful coiled tubing-conveyed hydroblasting intervention created an opportunity to effectively conduct a chelant-based hydrofluoric (HF) acid treatment that increased oil production by as much as 305% on the well (Sopngwi et al. 2014).
An Innovative Integrated Methodology to Deliquify Gas Well Using In-Well Live Performance Coiled Tubing for Velocity String Selection and Deployment: A Case Study in Saudi Arabia
Authors: Asel S. A. , Gomez F. A. , Ahmed D. , Baez F. , Elsherif T. , Kneina M. A. , Kharrat W. 
Published: June 2014

Abstract
Gas well deliquification is the process of removing water or condensate loading from producing gas wells. Water can be loaded into producing gas wells as a result of: an intervention where the well had to be loaded with water or completion fluids because of well control issues; stimulation fluids injected into the well; producible water zone below the gas zone; or well producing wet gas. Whereas, condensate banking can happen both in wet gas wells and retrograde gas condensate wells where condensate loads into the well or banks in the near wellbore region respectively, as a result of producing below dew point.
A number of techniques employed to deliquify gas wells include deploying an artificial lift system, installation of velocity string and stimulation. Artificial lift systems can include deployment of electrical submersible pumps, progressive cavity pumps, bean pumps, plunger pumps, and gas lift. Coiled tubing (CT) can be used to nitrogren lift the well or used as a velocity string, and stimulation can cover matrix stimulation or hydraulic fracking of the well.
Numerical and analytical software modeling can be performed prior to deploying each of the above mentioned techniques. In this case study after performing intensive modeling, different solutions were proposed but the question is which most efficient and cost effective technique to use?. Thus, In-Well Live Performance CT (I-WLPCT) was the selected technique because it is equipped with downhole pressure, temperature, casing collar and gamma ray sensors along with distributed temperature sensing for real time evaluation of the velocity string, determination of fluid level in the well, conducting surveillance under flow/shut-in test conditions and its results used to validate the software modeling.
This paper describes a case study of a retrograde gas condensate well and the challenges encountered during the successful implementation of an engineered approach with the aid of I-WLPCT to successfully select and deploy a velocity string for gas well deliquification.
2 3/8; and 2 7/8 OD Coiled Tubing Operations in Gulf of Mexico GoM Shelf: A Safe, Reliable, and Efficient Way to Prepare for Re-Entry of Wells to Conform to New BSEE Regulations
Authors: Torres Carlos , Ottolina Renny , Rudnik Alexander , Creppel Carl , Bergeron Ernest , Broussard Mike 
Published: June 2014

Abstract
Since the Bureau of Safety and Environmental Enforcement (BSEE) released and implemented the updated version of the Code of Federal Regulations (CFR) in recent years, Operators now have the need to reenter wells that had been deemed as abandoned in the 1980’s, and perform operations to comply with the updated regulations.
All of these wells have surface plugs (either cement plugs or cast iron bridge plugs) that require milling in order to access the wellbores to be abandoned. The use of a pulling unit is generally the method used for these abandonment operations. However, the risks of having pressure trapped below those surface plugs, and the ability to maintain well control during milling operations with the pulling and jacking units (PJU) poses a great concern to the Operators. Upon evaluation, Shell decided to use large outside diameter (OD) coiled tubing (CT) to mill the surface cement plugs and the cast iron bridge plugs. The use of CT enabled several operational advantages, such as the ability to handle potentially live well situations safely and efficiently, faster operations to mobilize (mob) from well to well, the use of larger bottom hole assemblies (BHA) with mills manufactured to drift the different casings 7", 9 5/8" and 10 ¾" inner diameter (ID), ensure optimal downhole motor (DHM) performance and to provide efficient removal of solids from the wellbore back to surface.
This paper describes the CT operations performed on two shallow waters platforms projects in the GoM for Shell, where a total of 9 wells were intervened using 2 3/8" and 2 7/8" OD CT. The challenges encountered together with the developed solutions, equipment used, lessons learned are also discussed. Full compliance with BSSE regulations for well abandonment was the final result.
Cut & Cap Process for Surface Casing Vent Flow Repair and Prevention
Authors: Sahnoun Djillali , Schneider Jason , Sylvestre Chuck 
Published: June 2014

Abstract
Thousands of new wells are being drilled each year while thousands more are being repaired or abandoned around the world. Remedial and well abandonment work is becoming increasingly important for both E&P companies and energy service companies providers as the oil and gas industry continues to recognize the financial and environmental impact, while at the same time, authorities are tightening regulations.
Traditional abandonment and squeeze methods have not changed much over the past several decades which has resulted in little or no improvement on the successful repair and abandonment of wells. While improvements have been suggested and trialed, remedial work is viewed as a cost burden, and companies tend to avoid it rather than to address it, which often leads to problems occurring or reoccurring in the future.
However, in Western Canada one particular technique has been successfully developed. Although not a new technology, abrasive jetting has proven to be one successful component in well repair operations in many parts of Alberta. Abrasive jetting was primarily developed for wells presenting surface casing vent flow (SCVF) problems. According to the Alberta Energy Regulators (AER), approximately one in 20 oil and gas wells in Alberta experience gas migration to surface through one of the following issues: a cemented casing string(s) with either a micro-annulus between casing and cement, a channel within the cement sheath, or a channel between the cement and the borehole wall. To remediate these possible gas migration passages, the abrasive jetting technique is used first to radially cut the casing, the cement sheath, and the formation in the horizontal plane utilizing a high-pressure sand/liquid mixture. Cutting in this manner provides full radial exposure and increases the chances of intercepting the gas flow passage.The next step is to determine the formation feed rate. Once the feed rate is determined, the proper product can be selected along with the placement technique. Micro-fine cement with slow-rate pumping is often used in the squeeze process to seal off the channels.
This process is highly effective in terminating gas migration (GM) or SCVF and reducing remedial costs, saving E&P companies thousands of dollars in rig time and material costs, and adding significant value for the client.
Perforating and Pipe Recovery with Digital Slickline First Application in Colombia Ballena Field
Authors: Arcila G. P. , Perez L. H. 
Published: June 2014

Abstract
As part of an abandonment campaing started in Feb 2013, Chevron had decided to permanent plug 3 gas producer wells and 2 water producer wells in the Ballena Field, with the main challenge of the footprint of equipment to be used because the original locations were eroded by sea and there was no possibility to use a conventional work over rig. This document presents 2 case studies where a significant advance in the slickline technology that incorporates cutting-edge benefits such as real time visibility and interaction and control, while maintaining slickline advantage simplicity had overcome the project's challenges allowing time and cost reductions.
Managing Risk and Reaping Reward in a High Temperature, High H2S, Extended Reach Environment: A Case Study of a Coiled Tubing Stimulation Campaign in the UAE
Authors: Quinn Sean , Chrysovulou Christina , Erickson Daniel , Singh Basant K. , Haryanti Dwi , Bowen Greg J. 
Published: June 2014

Abstract
Coiled Tubing (CT) interventions, even in simple environments, carry inherent risk. This risk is further compounded as the intervention envelope is expanded and the environment made more complex. This gas field in the UAE is an example of such a reservoir. The high temperatures and high levels of both H2S and CO2 present in the field make this an unforgiving environment. The drilling strategy dictates a substantial number of long, horizontal, dual lateral wells to target different sections of the reservoir which in turn vary significantly in reservoir quality. Finally, the production strategy stipulates that wells require acid stimulation with CT selected as the preferred placement technique.
Meeting all of the above requirements in a single intervention strategy requires extensive and careful pre-planning and hazard analysis and identification at the onset of such a project. The obvious challenges relate to the selection of a suitable CT string for such a job and subsequently protecting it from attack from H2S, complicated by extended exposure to acid. The more subtle challenges lie in the appropriate selection and combination of downhole tools technologies to achieve the multiple objectives of lateral access, extended reach capability and stimulation efficiency in a single bottom-hole assembly (BHA).
To achieve all of these multi-level objectives, this paper will review the planning, execution and post-job phases of the CT stimulation campaign completed in this gas field. Focus will be given to the initial Hazard Identification Study (HAZID) carried out and the subsequent actions taken to mitigate the risks identified. These include but are not limited to the design of the CT string, the selection of the stimulation strategy including laboratory testing done for fluid selection and corrosion inhibition, a review of the various yard-testing conducted to select and set-up the required intervention BHAs, and finally the integration of a new, real-time CT pipe monitoring system to affirm the effectiveness of the pipe management and mitigation strategy used.
The results reaffirm the value of investing time upfront to conduct a HAZID and then do the necessary due diligence to follow through on action items and implement engineered solutions. Furthermore, the workflows and best practices resulting continue to be used and updated as the project continues.
Rheology and Flow Characteristics of Xanthan in Calcium Chloride Brine
Authors: Asafa Kolapo A. , Shah Subhash N. 
Published: June 2014

Abstract
Xanthan gum and other naturally obtained polymers have been used extensively in the petroleum industry as a "viscosifier" in drilling, completion, workover and hydraulic fracturing fluids. Other than the effects of shear rate, pH and temperature, the performance of various polymers can be greatly affected by salinity, due to their sensitivity to metal ions of different salts contained in the commonly used solvents. In today’s oilfield operations, it is not uncommon to combine polymers with sea water or brine of a known salt concentration in order to generate certain desired fluid properties. Consequently, the importance of understanding the compatibility and shear properties of polymer fluids in brine solvents for coiled tubing operations cannot be underemphasized.
However, while there are several existing literatures on the various methods of viscosifying brine solutions with polymers, only a handful have attempted to describe the flow properties of viscosified brine. In order to bridge this knowledge gap, the present experimental study examines the compatibility and flow characteristics of Xanthan gum at various polymer loadings with different concentrations of Calcium Chloride (CaCl2) brine. An unprecedented set of flow data was acquired using an experimental flow-loop comprising of ½ in. straight and coiled tubing sections. The data demonstrated a continual decrease in drag reduction and increased friction pressure loss with increasing brine density. A comparison of those data with predicted data show that the hydraulic properties of viscosified brine can be fairly estimated using existing friction factor correlations. Nevertheless, additional flow data must be acquired with various brines and polymers to develop correlations with better accuracy.
The Journey Continues: Sixty Years of Sharing Incident Information in the Geophysical Industry
Authors: Threadgold Ian M. 
Published: June 2014

Abstract
For more than sixty years the geophysical industry has been taking a journey towards greater safety and security for its workforce. In the early 1950’s, a worker in the geophysical sector of the petroleum industry was five times more at risk of injury than workers in other sectors of the same industry. Today a worker in the geophysical sector is at par with other oil and gas industry workers in terms of their safety.
It is the author’s intention to highlight the data available regarding safety statistics over the last six decades, and offer a brief review of which groups were stewarding safety issues during this same period. The paper looks at how the sharing of incident information began in the geophysical industry over 60 years ago and has continued to this present day. This sharing of incident information, for such a prolonged period of time, has been unique to the geophysical sector of the oil and gas industry.
A case is made that this sharing of information is the largest single factor in the dramatic improvement in safety performance within the geophysical sector of the petroleum industry. Mention is also made of how this sharing in the present day has led to the creation of a fatality and high potential incident database, again unique to the geophysical sector. It is hoped that this story may help encourage other sectors in the oil and gas industry to improve the sharing of incident information.
New Evidence on the Drivers of HSE Incidents and Reporting, and Implications for HSE Policy
Authors: Jablonowski Christopher J , Tolle John J. 
Published: June 2014

Abstract
This paper specifies detection-controlled regression models to investigate the drivers of health, safety, and environmental (HSE) performance and reporting behavior. The analysis confirms some results from previous research and also tests new hypotheses, with emphasis on supervision-related practices and policies. Most of the results are general and thus applicable to other regions, to other operators, and very likely to other industrial sectors. The results can be used to drive decisions regarding operating practices and HSE management system policy.
Oil and Gas E&P Cyber Security: Perfect Storm Threat Review
Authors: Smith Andrew L 
Published: June 2014

Abstract
Critical Infrastructure Protection (CIP) relates to the challenges posed by ‘High Impact, Low Frequency Risks’.1 World-wide critical infrastructure interdependencies also exist across the globe.2
The risk of a coordinated cyber, physical, or blended attack against CIP systems has become more acute over the past 15 years as digital communicating equipment has introduced cyber vulnerability to the system, and resource optimization trends have allowed some inherent physical redundancy within the system to be reduced. The specific concern with respect to these threats is the targeting of multiple key nodes on the system that, if damaged, destroyed, or interrupted in a coordinated fashion, could bring the system outside the protection provided by traditional planning and operating criteria. Such an attack would behave very differently than traditional risks to the system in that an intelligent attacker could mount an adaptive attack that would manipulate assets and potentially provide misleading information to system operators attempting to address the issue.
More comprehensive work is needed, however, to realize the vision of a secure CIP system. Better technology solutions for the cyber portion of the threat needs to be developed, with specific focus on forensic tools and network architectures to support graceful system degradation that would allow operators to "fly with fewer controls." Component and system design criteria also need to be re-evaluated with respect to these threats with an eye toward designing for survivability. Prioritization of key assets for protection will be a critical component of a successful mitigation approach.
Consequently, there needs to be a significant shift in industry specific standards by referencing active security monitoring, security intelligence and specially designed forensics tools. The review will address the latest developments in information protection, threat mitigation, behavioural and intrusion detection, situational awareness and defending against advanced persistent threats (APT’s) 3.
The global oil and gas businesses cannot close their eyes to this threat and hope it will go away or won’t happen to them. They must begin defending themselves now against the Perfect Storm.45678
HPHT Cement Sheath Integrity Evaluation Method for Unconventional Wells
Authors: Shadravan Arash , Schubert Jerome , Amani Mahmood , Teodoriu Catalin 
Published: June 2014

Abstract
Chances of cement sheath failure increase considerably when the application involves deepwater, high pressure high temperature (HPHT) conditions. Such failures may occur as a result of temperature and pressure-induced stresses created by well events such as hydraulic fracturing, cyclic steam injection, steam assisted gravity drainage (SAGD), production, completion, or other remedial treatments. Thermal and stress cycles could impose the risk of losing zonal isolation and lead to delay in hydrocarbon production.
Cement mechanical properties measurment solely would not be sufficient to predict the failure threshold of a cement sheath. Some experimental studies were conducted about the effect of cyclical loading on the integrity of casing and drill strings but less research have been done about the in situ cement sheath integrity under cyclical loading. This paper introduces a new Ultra HPHT experimental set up and an applicable method to evaluate cement sheath integrity under cyclical loading. It also provides insights to find the cement fatigue failure cycle for the set cement at elevated pressures and temperatures.
This system was built and completed by benefiting from the capabilities of an extreme HPHT Rheometer. Cement samples could be cured for number of hours in the newly developed HPHT cell and then instantly tested under cyclical loading in various scenarios at high temperatures. The cement sheath fails after a certain number of cycles when reaches its fatigue endurance limit. This research showcases scenarios in which the fatigue failure cycles were identified for 1,000 psi, 2,000 psi and 5,000 psi, pressure differentials between the confining pressure (exposed to outside of the sheath) and the casing pressure. During these experiments, the confining pressure and temperature were held constant at 15,000 psi and 330°F while the casing pressure varied cyclically between 15,000 psi and 16,000 psi (Set A), 17,000 (Set B) and 20,000 (Set C). A stable chemistry of Class H cement plus 35% silica was used to prevent cement retrogression. Cement sheath failures such as radial cracking, debonding and disking occured due to cyclical loadings. Finally, a fatigue failure envelope was generated by the obtained data. This curve represents the extent of cement sheath endurance at HPHT conditions under cyclical loading.
A Seachange in Environmental Capability Development
Authors: Walls Anne , Walker Sam , O’Brien Rob , Yoder James 
Published: June 2014

Abstract
Offshore exploration and production continues to be a major focus for the oil and gas industry, with the deepwater accounting for over 50% of all conventional new reserves discovered worldwide between 2007 and 2012. Like most oil and gas companies, BP has a dedicated and committed team of environmental advisors. However, a need to strengthen capability in marine science was identified. No courses were available commercially that offered suitable marine science training to develop the skills required, and to keep advisors up-to-date with new advances in scientific understanding and techniques.
In 2011, BP worked with the Woods Hole Oceanographic Institution (WHOI), Massachusetts to develop a two week course in marine science that would provide an in-depth understanding of the fundamental physical, chemical and biological aspects of marine science, and application of those fundamentals in an industry context. The syllabus developed also provides an insight into the practical aspects of marine science through tours of the WHOI laboratories and facilities and an offshore planning, sampling and data collection exercise.
The course was run in 2011 and 2012, with a total of 37 delegates from 13 countries attending. The benefits to participants have been high, with some even moving to new roles based on their acquired expertise, and the company now has a large resource base of capable marine scientists who are better equipped to manage marine projects and operations. WHOI has also benefited as the course gives staff and students direct exposure to industry representatives, enabling them to better understand the industry context. Each year, feedback was sought and incorporated into the syllabus in order to continuously improve the learning offer for participants.
This experience has demonstrated how, through partnership with world-class academic institutions, it is possible to develop high-quality environmental training offers that develop much needed capability for the industry. This paper will examine how the WHOI course has been made a success, what the benefits of this type of training are (to individuals and to companies), and what options are available for maintaining and further developing marine science capability going forward.