bluuebunny/crossref_metadata_2025 huggingface dataset:
A study of peripartum cardiomyopathy in a tertiary care center in India
Authors: Joshi Aditi V. , Fonseca Michelle N. , Kharat-Kapote Deepali S.
Published: January 2017

Background: Peripartum cardiomyopathy is an idiopathic and reversible form of dilated cardiomyopathy. The aim of the study was to study the mean age of presentation of peripartum cardiomyopathy in pregnant patients over a period of 1 year in a tertiary health care and study the maternal and fetal outcome of patients with peripartum cardiomyopathy.Methods: A retrospective observational study with total of 22 patients with peripartum cardiomyopathy was diagnosed in a total of 10,279 deliveries conducted at LTMMC, Sion hospital between September 2014 to February 2016.Results: Our study revealed that most of the affected patients were young with the mean age at presentation being 26.8±4.29 years. Most of the patients were diagnosed in the postpartum period (63.6%). the most common risk factor was pre-eclampsia (22.7%) followed by anemia (18.2%). The mean Ejection fraction at the time of presentation was 25.3±9.8%. There were 2 (9.1%) intrauterine fetal deaths and 1 neonatal death.Conclusions: There is a need for more multi-centric studies in order to understand the underlying pathogenesis and to determine the possible early interventions to help provide better pregnancy outcome.
Retrospective study of massive obstetric haemorrhage and its materno fetal outcomes in a tertiary care centre
Authors: Padmasekar Anju , Jothy Shyamala
Published: January 2017

Background: Massive obstetric haemorrhage is defined as blood loss of >1500 ml, or a decrease in haemoglobin>4 gm/dl or acute transfusion requirement of >4 units of blood when need for further transfusion is foreseeable. The purpose of this study is to analyse the demographic, medical and obstetric risk factors for massive obstetric haemorrhage and it’s materno fetal outcomes.Methods: Criteria for patient selection was all patients who had an acute obstetric haemorrhage necessitating a transfusion of >4 units of blood at a stretch when there was a need for more. This is a retrospective study conducted for a period of one year January to December 2015. Data regarding all cases under study during this period was obtained from Medical Records Department with prior permission. This study was conducted in the Department of Obstetrics and Gynecology, Government Raja Mirasudhar Teaching Hospital, Thanjavur Medical College, Tamil Nadu. Maternal outcomes like mode of delivery, rate of hysterectomy, postpartum complications, maternal mortality and fetal outcomes like intra uterine death, still birth and preterm birth were analysed.Results: The rate of massive obstetric haemorrhage in our hospital during the study period was 5.7/1000 births. Massive obstetric haemorrhage contributed to 25% of all maternal deaths in 2015. Atonic PPH was the commonest cause. Multiparity and previous caesarean section were identified to be significant risk factors.Conclusions: We found an increased association of massive obstetric haemorrhage with multiparity, caesarean sections and pre-eclampsia. Atonic PPH was the commonest cause. Massive obstetric haemorrhage had contributed significantly to adverse maternal and perinatal outcomes.
A study to correlate histopathological findings in patients with abnormal uterine bleeding
Authors: Shukla Mansi , Fonseca Michelle N. , Kharat Deepali , Tekale Pallavi
Published: January 2017

Background: Abnormal uterine bleeding (AUB) is a common gynecological problem associated with considerable morbidity and significantly affects the patients. The aim of the study was to analyze the histopathological patterns of endometrium in patients presenting with AUB and also to determine the incidence of AUB in various age groups.Methods: This is a retrospective study, conducted in the Department of Obstetrics and Gynaecology, in a tertiary care teaching hospital, Mumbai, India from March 2016 till date. All cases of AUB were included in the study. Data was entered in microsoft excel and managed in statistical package for the social sciences (SPSS) version 16. Analysis was done in the form of percentages and proportions and represented as tables where necessary.Results: A total of 120 cases were analyzed. Patients’ age ranged from 22-79 years. AUB was most common among the perimenopausal females (41-50years). The most common presenting symptom was heavy menstrual bleeding (53%). Dilatation and curettage (D&C) was performed in all cases and 96 underwent hysterectomy as final resort. Endometrial proliferative pattern was the most common histopathological finding and was seen in 27% patients, followed by endometrial hyperplasia in 13.5% patients, secretory endometrium (12.7%) and disordered proliferative endometrium were seen in 10.9% patients each. Malignancy was detected in 1.7% of cases and endometrial carcinoma was the most common lesion.Conclusions: Endometrial sampling is especially indicated in women above the age of 35 years to rule out malignancy and preneoplasia. Among the females with no organic pathology, normal physiological patterns with proliferative, secretory, and menstrual changes were observed. The most common endometrial pathology in this study was endometrial proliferation.
Outcome of immediate postpartum intrauterine contraceptive device in caesarean versus vaginal insertion: a comparative study
Authors: Shanavas Aswathy , Jacob Sujamol , Chellamma Nirmala
Published: January 2017

Background: Immediate Postpartum Intrauterine Contraceptive device is a novel approach to contraception which integrates Maternal - Child health and family planning services. It is a postpartum method which provides long term reversible contraception to women before discharge from the delivery setting. More research is needed in the field of PPIUCD to enhance awareness and acceptance in the community. This study is designed to compare the safety and efficacy of PPIUCD inserted at cesarean versus vaginal delivery.Methods: This is a prospective study conducted at Sree Avittom Thirunal Hospital, Govt. Medical College, and Kerala – A tertiary care teaching institution. A total of 126 patients with cesarean or vaginal deliveries had PPIUCD insertions and they were followed up for a period of one year. The outcome measures analyzed were safety measures – menstrual irregularities, vaginal discharge, pelvic infection and perforation and efficacy measures - failure, expulsion and removal. Data are expressed in frequency and percentage. Chi square test was used for comparison and P value <0.05 was considered significant.Results: The study shows that PPIUCD is an effective intervention in both cesarean and vaginal delivery with no significant differences in safety and efficacy depending on the route of insertion. There was no case of perforation or failure and no significant risk of infection in either group. Spontaneous expulsion occurred in two cases inserted by vaginal route. Missing string incidence is high in the cesarean group compared to vaginal insertion.Conclusions: PPIUCD is a safe effective and convenient method of contraception and should be encouraged in both vaginal and cesarean deliveries.
Role of mifepristone in induction of labour in pregnant women with previous lower section caesarean section with IUFD in late preterm and term pregnancies
Authors: Deora Ram Kanwar , Shetty Nikhila G.
Published: January 2017

Background: The objective of the study was to evaluate efficacy and safety of oral mifepristone for preinduction cervical ripening and induction of labour in late preterm and term pregnancies with previous caesarean section with intrauterine fetal demiseMethods: This prospective short term study was conducted at Umaid hospital SNMC Jodhpur Rajasthan January 2016 to November 2016. 100 subjects with previous uses beyond 34 week with intrauterine fetal demise and bishop’s score<6 were included. Tablet mifepristone 200mg was given orally after taking written in informed consent. The same dose was repeated after 24 hour according to bishop’s score. Analysis was done with respect to maternal outcome of vaginal delivery, CS, duration of labour.Results: Among 100 subjects, 97 delivered vaginally (97%) delivered within 72 hour of 1% dose. Improvement of bishop’s score was observed in 1 subject (1%), which later required augmentation by oxytocin followed by vaginal delivery.1 subject (2%) failed to respond and required caesarean section, 72 hour after given of 1st dose.Conclusions: Mifepristone can be used safely and effectively for induction of labour in previous one and two LSCS near term and term pregnancies to avoid CS rates.
Sterile water injection labour analgesia in a parturient with preeclampsia with thrombocytopenia
Authors: Panwar Shivali , Arora Divya , Kapur Anu , Saxena Kirti Nath
Published: January 2017

Pregnancy induced hypertension is one of the most common causes of maternal morbidity and mortality. A G2L1A1 female with period of gestation 36 weeks presented in our hospital with early labour pains. She was a known case of pregnancy induced hypertension with thrombocytopenia and had been operated on the lumbar spine for Potts spine. She was administered intradermal sterile water injection labour analgesia every 3 hours. The labour was uneventful and patient had a normal vaginal delivery of a male baby. The postnatal course was uneventful and patient was satisfied with the labour analgesia.
Study of vitamin D status and bone age in children with Thalassemia major
Authors: Dr.Hardik Shah*** Dr. Bela Shah*,Dr.Dhara Gosai**,
Published: January 2017

Objectives: To study Vitamin D levels and bone age estimation in patients with thalassemia major and to correlate various factors associated with short stature, Vitamin D deficiency and bone age difference. Study Design: Prospective observational study Setting: Thalassemia clinic, Civil hospital, Ahmedabad Subjects and intervention: Total 84 patients with Beta-thalassemia major less than 12 years of age during 1 month period were included after taking informed consent. Study period: 15 October 2016 to 15 November 2016 Results: Out of 84 patients 34 patients had Vitamin D deficiency(<20ng/ml), 34 patients had short stature and 24 patients with bone age >36 months had age>10 years. Vitamin D levels <30ng/ml is associated with ferritin level >2500(mcg/l)(OR=2.23 p=0.02 95%CI). Age>10 year(OR=7.7 P=0.0001 95%CI) and ferritin >2500mcg/l (OR=1.9 P=0.1 95%CI)are associated with bone age difference>36 months. Increased S.ALP(OR=1.1 P=0.02 95%CI) and ferritin levels>2500 mcg/l (OR:3.6 P=0.0056 95% CI )are associated with short stature. Conclusion: Vitamin D and calcium supplementation along with disciplined transfusion and chelation regimen can likely prevent or delay late complications like short stature, osteoporosis in thalassemia patients.
Analisis Kerentanan Pulau-Pulau Kecil di Kecamatan Togean Kabupaten Tojo Una Una Provinsi Sulawesi Tengah (Studi Kasus P. Kukumbi, P. Enam, P. Mogo, P. Kadidiri, P. Pagempa, P. Tongkabo)
Authors: Akbar Mohamad
Published: January 2017

This research was conducted in small islands area to Togean District, TojoUna-Una Regency Central Celebes by ecological and sosio-economic approach.  Methods those used in this research were vulnerability index, MCDM (multi criteria dimension making) and Geographycal information system (SIG) approach.  Data was collected bt participative and explorative approach.  Data analysed parameters using vulnerability, assessment method involved vulnerability variable parameters i.e. area characteristic, area degradation, sea level rise, human impact, economic exposure, economic remoteness.  The results shows the range ofcomposit vulnerability index for ecological (CVI-Ek) is 0.00-0.77, economic (CVI-En) is 0.00-0.75, and composite vulnerability ecological-economic (CVI-EE) is 0.00-0.76.  Enam island (0.76)and tongkabo island (0.66) is rated to high vulnerable (0.67), Mogo Island (0.14), Kukumbi Island (0.12), Pagempa Island (0.09) and Kadidiri Island (0.07), is considerednon vulnerable.  MCDM analysis result that is used to determine small island management model in Togean District, shows ecological criteria is most important compared with economy criteria and social criteria.  Analysis of SMART technique  shows the type small islands  sustainability management  scenario in Togean District, those are scenario A (adaptation, 0.94) and scenario B ( without adaptation, 0.55).Keywords : small island, composite vulnerability index, sustainability, togean district.
Analisis Kandungan Zat Pengawet Boraks Pada Sampel Jajanan Bakso di Desa Jatipurno Kabupaten Wonogiri
Authors: Swastike Winny , Emawati Shanti , Sari Ayu Intan
Published: January 2017

Wonogiri an area that is well known as an area where people are dominated by traders meatballs. Type meatballs offered vary from meatballs served with noodles in the form of soup or meatballs are sold singly or known as grilled meatballs. Things are very concerned about is the use of borax in meatballs often functioned as chewing of food. Borax poisoning can occur through food, one of which is meatballs as one type of food that is very familiar. This study aimed to analyze the content of borax in food, especially meatballs in Jatipurno village, Wonogiri. This type of research is descriptive laboratory with laboratory tests are qualitative and quantitative methods of flame with acid-base titration method. The population is all hawker meatballs in Jatipurno village, Wonogiri. Sample was taken by purposive sampling of each meatball sellers. The experimental results on samples compound identification borax meatballs with flame method, note that of the 50 samples tested meatballs did not produce a green flame which means not detected borax content in the samples. The final conclusion is that the meatballs were analyzed by flame proving that the sample was circulated in Jatipurno village, Wonogiri is not identified free of borax and borax content. Not to do quantitative research to determine levels of borax meatballs snacks for the qualitative research produces a negative value (does not contain borax).

 

Keywords: Food Additives, meatball snacks, borax
Tandem Downhole-Isolation-Valve System Eliminates Snubbing
Authors: Wilson Adam
Published: January 2017

This article, written by Special Publications Editor Adam Wilson, contains highlights of paper SPE 173043, “First Ever North Sea Deployment of Tandem DIV System Eliminates Snubbing—A Case Study,” by Gary Mueller, Weatherford, prepared for the 2015 SPE/IADC Drilling Conference and Exhibition, London, 17–19 March. The paper has not been peer reviewed.

The operator of an offshore jackup rig in the North Sea required safe and efficient deployment of the completion string without killing the well during tripping. A solution other than a snubbing unit was needed because of the length of the completion string, which included 12 swellable packers for 13 zones. To provide for a safer, less-expensive, and efficient method of tripping pipe, the operator chose a downhole-isolation-valve (DIV) solution that allowed for the process to be performed in a conventional manner under conditions of complete well control.

Introduction

During the past decade or so, the industry has developed drilling methods to address more-complex and - challenging prospects such as ultradeep prospects, deepwater applications, and high-pressure/ high-temperature wells in order to continue meeting the worlds’ demand for energy. This seemingly insatiable demand has led to the development and widespread use of unconventional techniques such as underbalanced drilling (UBD) or near-balanced drilling and various forms of managed-pressure drilling, including pressurized-mud-cap drilling (PMCD) and constant- bottomhole-pressure drilling with their attendant well-control and safety challenges. Some of these challenges are

Moderate to severe lost-circulation conditions and consequent nonproductive time (NPT)

Formation damage as a result of having to kill the well before tripping pipe

Pore-pressure and fracture-gradient similarity leading to kick and loss cycles and well-control problems

A necessity for snubbing techniques to trip the pipe in and out of the hole above the “pipe light” depth, with the attendant added cost and risk

Overall operational safety and environmental issues

Operational economics and the effect of resulting NPT

As a result of these challenges, mitigating drilling hazards has become an extremely important facet of drilling operations and has prompted the development of procedures and equipment designs to address them, one of which is the DIV.
Managed-Pressure-Drilling Technology Delivers Challenging HP/HT Drilling Campaign
Authors: Carpenter Chris
Published: January 2017

This article, written by JPT Technology Editor Chris Carpenter, contains highlights of paper SPE 175479, “MPD Technology Used To Deliver Challenging HP/HT Drilling Campaign,” by Robert Graham, Martin Geddes, Tim Harris, Dominic Flaherty, Nigel Shuttleworth, Bruce McEwan, Noor Nordin, Michael Cadd, John O’Grady, and Pete French, Shell, and Richard Sandell and Stuart Jeffries, Blade Energy Partners, prepared for the 2015 SPE Offshore Europe Conference and Exhibition, Aberdeen, 8–11 September. The paper has not been peer reviewed.

The Shearwater field is a deep, high-pressure/high-temperature (HP/HT) reservoir located in the UK Central Graben of the North Sea. A high level of reservoir depletion (greater than 8,000 psi) has resulted in significant changes to the drilling envelope that has added complexity to the drilling practices required to exploit the remaining reserves successfully. Managed-pressure-drilling (MPD) technology was implemented in conjunction with drill-in liner and wellbore-strengthening technologies to successfully deliver the first well in a redevelopment campaign and prove the techniques required to prolong field life.

Shearwater Overview

Shearwater is an HP/HT gas/condensate field discovered in 1988. Primary production is from the Fulmar, a sandstone reservoir with virgin pressure of 15,400 psi and temperatures greater than 360°F. The field came on stream in 2001. The large field-pressure depletion resulted in compaction at the Fulmar formation level and led to mechanical failure of the production liners because of shear deformation.

A drilling campaign to restore Fulmar production was initiated in 2013. The primary plan was to abandon the existing reservoir sections of the wells and perform shallow sidetracks from the 20-in. casing. A 16-in. hole was planned to the top of the Tor formation (above the pressure ramp), and a 12¼-in. hole was to be drilled into the top of the Cromer Knoll formation. 10×10¾-in. casing would be set across this hole section, and an 8½-in.-hole section would be drilled to just above the top of the Kimmeridge shale formation. A 7?-in. drill-in-liner system would then be used in conjunction with MPD and wellbore- strengthening material to drill into the top of the Fulmar reservoir. The reservoir was planned to be drilled with a 6½-in. hole size opened out to 7½ in., and the reservoir would be completed with a 7×5-in. production liner. The MPD objectives by hole section are discussed in detail in the complete paper.

MPD was planned as an enabling technology because of the tight fracture-pressure/ pore-pressure wellbore- stability window. Fig. 1 illustrates the planned wellbore configuration and the expected pressure profiles.
New Rotary Shouldered Connection Expands Capability of ERD Operation
Authors: Wilson Adam
Published: January 2017

This article, written by Special Publications Editor Adam Wilson, contains highlights of paper SPE/IADC 168049, “New Rotary Shouldered Connection Expands the Capability of World-Record ERD Operation,” by S.R. Sanford, SPE, and M.W. Walker, SPE, ExxonMobil; and J.N. Brock, M.J. Jellison, SPE, and A. Muradov, SPE, NOV Grant Prideco, prepared for the 2014 SPE/IADC Drilling Conference and Exhibition, Fort Worth, Texas, USA, 4–6 March. The paper has not been peer reviewed.

Eight of the world’s 10 longest wells have been drilled by ExxonMobil as operator of the Sakhalin-1 project in Russia. Components and drilling tools involved in the well design are evaluated and redesigned throughout the program to maximize penetration rate and reduce flat time. Drillstring-torque capacity was recognized as a limiter for increasing penetration rate and for reaching total measured depth capability. The operator consequently sought an alternative drillpipe connection with higher torque capacity.

Introduction

The Sakhalin-1 project comprises the Chayvo, Odoptu, and Arkutun Dagi fields off the east coast of Sakhalin Island, Russian Federation (Fig. 1). Development drilling at the Chayvo field started in 2003 with extended-reach wells drilled from an onshore location with the Yastreb drilling rig. In 2005, further development drilling commenced from the offshore Orlan platform site. Subsequently, in 2008, the Yastreb rig was moved approximately 75 km north to the Odoptu onshore wellsite and drilled nine extended-reach-drilling (ERD) wells as part of the initial-stage development of Odoptu. During the Odoptu campaign, it was determined that a higher-torque 5?-in. drillpipe connection with good runnability was needed. Following the Odoptu campaign, the Yastreb rig was moved back to the Chayvo onshore wellsite in 2011 for further development and infill drilling of the Chayvo reservoirs.

Limiter Identification

During the first drilling campaign at Chayvo, available topdrive torque limited drilling performance in the long production hole section (>3000 m). Installation of a new topdrive capable of continuous torque in excess of 90,000 lbf-ft at 140 rev/min eliminated this limiter. During the subsequent Odoptu drilling campaign, the 5?-in. drillpipe connection was identified as a new limiter affecting rate of penetration (ROP) and torque operating margin in the production hole section.
Norway Faces Up to Harsh Conditions
Authors: Rassenfoss Stephen
Published: January 2017

Offshore Norway is an unlikely spot for optimism. The continental shelf is home to a mature basin, with harsh sea conditions, a reputation for high costs, and an exploration frontier well north of the Arctic Circle.

Last year’s version of low oil prices, when benchmark crudes traded for around USD 50/bbl, led to news stories in Norway pointing out that the shares of the 10 largest local oil-industry-related companies, excluding Statoil, were worth less than the 10 biggest aquaculture companies.

While raising salmon is expected to grow into a big business, with big oil industry suppliers such as Kongsberg working on high-tech tools to raise millions of fish, those working in the oil business are not talking about a career change.

“Oil [/bbl] is selling for the same prices as 4.5 kilo salmon. We could all start farming salmon, but I do not think so,” said Arve Iverson, ROV operations manager for Oceaneering, at the recent Subsea Valley Conference in Oslo.

The show put on by the organization created to increase the visibility of the engineering-driven oil industry in southeast Norway, also amounted to a rally in support of the future of oil offshore Norway, and the global markets these companies_serve.

Eldar Sætre, the chief executive officer (CEO) of Statoil, pointed out that the national oil company has lowered its average break-even cost for new projects from USD 70/bbl to USD 40/bbl, and emphasized that the bulk of the improvement was in savings that will remain after supplier discounts are gone.

The themes of standardization, simplifying requirements, and working together were common ones when hearing from oil industry experts.

The test of whether the Norwegian industry can deliver on its goal of profitably producing oil in a era of low prices, is the Johan Sverdrup field, a multibillion-barrel find which is moving forward in the midst of the slump, showcasing innovations backed by the Norwegian government and Statoil.
Technology Focus: CO2 Applications
Authors: Kokal Sunil
Published: January 2017

Overview

Carbon dioxide (CO2) has been in the news a lot. We have all heard about global climate change. Chances are your child in elementary school has also heard about it. It has been center stage in all local, national, and international political and environmental debates. I am not going to talk about it here. What I am going to articulate here is what we can do about it in our own way. By “we,” I mean we as individuals, we as SPE members, and we as oil and gas industry professionals.

First, the bad news: Indeed, there are a lot of challenges with CO2. It is a stable compound and does not readily disintegrate. The biggest challenge perhaps is the cost of capturing CO2. Most of the anthropogenic CO2 is available from fixed sources such as power plants. The CO2 first has to be separated from nitrogen, then compressed, and finally piped and pumped into a subterranean reservoir for oil recovery or storage. All of these steps are expensive.

Now the good news: It can be done. And we, as petroleum engineers and Earth scientists, are best suited to do it. We know our reservoirs, we have produced from them, and we can ensure that CO2 can be sent back safely and securely into them. Supercritical CO2 is an excellent solvent, especially for lighter crude oils. If it were free, or as low in cost as water, we would be injecting CO2 instead of water for its favorable properties.

So how can we help? There are many areas and applications of CO2 in the oil and gas industry. CO2 enhanced oil recovery (EOR) is the bedrock and the mainstay in our application portfolio. A lot has been published in that area. At present, there remain several challenges with CO2 EOR. These include gravity override, poor sweep efficiency, and economic factors. Considerable work and research are ongoing to address all of these challenges. The papers that follow address some of them: an example of chemical-looping emerging technology in a bid to reduce CO2-capture costs; CO2 foams for improved oil recovery; commercial-scale demonstration projects; and use of CO2 in tight gas and unconventional resources. JPT

Recommended additional reading at OnePetro: www.onepetro.org.

SPE 169039 Development of Small- Molecule CO2 Thickeners for EOR and Fracturing by J.J. Lee, University of Pittsburgh, et al.

SPE 169022 Experimental Investigation of Enhanced Recovery in Unconventional Liquid Reservoirs Using CO2: A Look Ahead to the Future of Unconventional EOR by Francisco D. Tovar, Texas A&M University, et al.

SPE 171692 Carbon Capture and Storage for Enhanced Oil Recovery: Integration and Optimization of a Post-Combustion CO2-Capture Facility at a Power Plant in Abu Dhabi by A. Reichl, Siemens, et al.
A Novel Integrity-Assurance Approach for Qualification of Subsea Technologies
Authors: Carpenter Chris
Published: January 2017

This article, written by JPT Technology Editor Chris Carpenter, contains highlights of paper OTC 27296, “Development of a Novel Integrity-Assurance Approach for Technology Qualification of New Subsea Technologies by Deepstar,” by S. Furtado and H. Hamedifar, DNV GL; K. Mateen, Total; L. Huyse, Chevron; L.M. Rivero, Total; and G. Kusinski, Chevron, prepared for the 2016 Offshore Technology Conference, Houston, 2–5 May. The paper has not been peer reviewed.

A study has been conducted to develop a methodology in which integrity of the various components of a new technology can be quantified, even in the absence of failure data from the field. The study recognizes the importance of having a common understanding and definition of key principles used in technology qualification (TQ) and a common view of integrity-assurance-acceptance criteria in the oil and gas industry.

Introduction

The deepwater industry uses TQ as a tool to determine which safety barriers are needed, as well as what level of testing is required. TQs have traditionally focused on technical systems and capabilities at the component level. Much less attention has been given to systematic factors, however.

Knowledge of systems involves understanding of the integrity of technologies during design, construction, operation, and maintenance. It is accepted that there is a lack of common ground and consistency in qualifying new technologies in the subsea industry.

Qualification Approaches in Other Industries

Other industries, such as the nuclear, aerospace, and automotive industries, have a more established reliability-engineering history and address failure rates and mean life of systems and products in a numerical or quantitative manner. These industries make use of the following methodologies:

Immense amounts of monitoring data

Much lengthier qualification processes

Natural and frequent check and monitoring points

Uniformity of application

Weibull distribution

Regression analysis

Essentially, the three industries named deal with many components and systems that have undergone a lengthy qualification effort. Moreover, there is significant monitoring of the performance parameters. The systems and equipment in these industries have a much more uniform application range than those of the offshore industry. Finally, there are natural and repeated intervention or access points to the equipment for repair, maintenance, and checkup.

In the oil and gas offshore industry, applications are not uniform, access and monitoring are very limited, and the number of equipment items with meaningful failure data is minuscule compared with, say, hundreds of millions of automobiles on the roads.
How the Petroleum Industry Can Learn From the Ebola Crisis of 2014
Authors: Wilson Adam
Published: January 2017

This article, written by Special Publications Editor Adam Wilson, contains highlights of paper SPE 177759, “How the Petroleum Industry Can Learn From the Ebola Crisis of 2014,” by Andre Willemse, International SOS, prepared for the 2015 Abu Dhabi International Petroleum Exhibition and Conference, Abu Dhabi, 9–12 November. The paper has not been peer reviewed.

The Ebola crisis of 2014 was one of the worst infectious disease outbreaks in recent history. It also occurred in a region with endemic medical risks and poor medical infrastructure. These two factors make it an important learning exercise for the global petroleum community. This paper reviews the Ebola outbreak from the viewpoint of an onshore and offshore petroleum operator, providing insight into the real threats the outbreak presented by looking past the media hype and diving into the real organizational effects of the outbreak.

Introduction

West Africa experienced the most severe Ebola virus disease (EVD) outbreak ever recorded. The most-affected countries are Liberia (10,672 cases as of 16 August 2015), Sierra Leone (13,494 cases), and Guinea (3,786 cases). Other affected countries include Mali, Nigeria, and Senegal in Africa; and Italy, Spain, the United Kingdom, and the United States, although to a much lower level. Pictorial representation of the number of cases and deaths in affected countries as of 5 July 2015 is shown in Fig. 1.

The World Health Organization on 6 August 2014 declared this Ebola outbreak in West Africa to be a public health emergency of international concern.

Lessons Learned

The West Africa Ebola outbreak has been the largest, longest, and most complex since the virus was discovered in 1976. It has had the highest number of cases and deaths ever reported for Ebola.

A functional health system is a prerequisite for any coordinated preparedness for and response to any possible outbreak. The 2005 revision to the International Health Regulations (IHR) is a legally binding agreement whose purpose is “to prevent, protect against, control, and provide a public health response to the international spread of disease in ways that are commensurate with and restricted to public health risks, and which avoid unnecessary interference with international traffic and trade.” None of the most-affected countries were compliant with the IHR regulations, and this surely delayed the timely identification of the disease, the setting up of contact tracing and adequate surveillance measures, and the early implementation of infectious control measures in healthcare settings.
Comments: Dubai Hosts Annual Meeting
Authors: Donnelly John
Published: January 2017

Later this month, the SPE Annual Technical Conference and Exhibition will be held in the Middle East for the first time. The conference will take place 26–28 September at the Dubai World Trade Centre. The locale not only underscores the region’s undaunted significance in the global oil and gas industry but also SPE’s continued international growth.

SPE has had a presence in the Middle East region for more than 50 years. In 1958, the SPE Board of Directors reorganized its basic organizational structure to take into account SPE’s rapid growth in membership. The board divided the Society into 11 separate regions, including one that encompassed Saudi Arabia. This was shortly before the creation of the Organization of Petroleum Exporting Countries (OPEC), of which Saudi Arabia was one of four founding member countries.

In 1961, SPE held its first significant program outside of North America. The first Regional Petroleum Technology Meeting, sponsored by the SPE Saudi Arabia Section, took place in Dhahran, with registration totaling 132 people representing 14 companies. The Saudi section had grown to 150 members in a little over a year since its creation.

Middle East membership growth continued and, in 2003, SPE created its first office in the region in Dubai to serve not only the Middle East but also North Africa. The region’s membership totals more than 13,000 professional members and more than 4,000 students, participating across 17 sections and 34 student chapters.

The Middle East has long been the focal point of the global oil industry and the latest BP Statistical Review of World Energy highlights the region’s dominant presence, as well as points out some changes taking place. Middle East energy consumption grew 4.2% in 2015, roughly in line with its 10-year average, and is growing faster than other regions around the world. About half of Middle East energy consumption is now natural gas, surpassing demand for oil. Oil output in the region grew 1.5 million BOPD last year to a record high 30.1 million BOPD, according to the Review, with production growth led by Iraq and Saudi Arabia.

The Middle East holds about 47% of the world’s proven crude reserves, almost 16% of those by Saudi Arabia alone, with Iran and Iraq holding 9.3% and 8.4% of the global total, respectively. The region has approximately 43% of total global gas reserves, with Iran claiming more than 18% and Qatar 13%.

This is the third time SPE has held its premier annual meeting outside the US. The conference took place in Florence, Italy, in 2010, and in Amsterdam in 2014. The meeting is not only an annual gathering for members but a platform for the latest technology trends and breakthroughs as well as a forum for discussing contemporary issues.

This year’s conference is no different, with panel sessions on operating and thriving in difficult times, preparing for a low-carbon era, changes companies are making to survive in a low-price environment, and handling data and analytics. For a complete schedule of technical sessions and events, please go to www.spe.org/atce/2016. JPT
Technology Update: A Holistic Approach To Controlling Torsional Dynamics in the Drillstring
Authors: Lines Liam
Published: January 2017

Technology Update

Understanding drilling dynamics, the downhole shock and vibration that occur while drilling, is a crucial step to improving drilling efficiency and reducing nonproductive time (NPT).

Industry statistics suggest that 20% to 30% of all downhole failures are related to adverse drilling dynamics (SPE 127413 and SPE 98150), and that drilling tool providers spend roughly USD 750 million per year on repair and maintenance. This amount pales compared with the untold costs borne by exploration and production companies as the result of drilling and completion inefficiencies, NPT, and tools lost in the hole.

Preventing adverse dynamics requires a strong understanding of the fundamentals, particularly in addressing torsional dynamics: time-based variations in downhole rotational speed and torque.

A common misconception is that torsional dynamics is limited to stick/slip. However, stick/slip is only one of three distinct modes of torsional dynamics, each with its own unique indicators, potential for damage, effect on drilling efficiency and—importantly—most effective means of mitigation.

Differing Dynamics

In addition to full stick/slip (FSS), the modes include low-frequency torsional oscillation (LFTO) and high-frequency torsional oscillation (HFTO) (Fig. 1). LFTO and FSS both typically occur at less than 2 Hz; HFTO occurs at between 50 and 250 Hz.

LFTO, probably the most common of all three modes, is the excitation of a fundamental torsional natural frequency of the drillstring. The excitation causes the drillstring to act as a long torsional spring, which results in sinusoidal oscillations in bit speed and torque. The oscillation frequency is a function of the drillstring length and stiffness, and is typically less than 0.5 Hz for all drillstrings (SPE 21945). LFTO is characterized by a maximum revolutions per minute (RPM) of up to twice the average drillstring RPM and a bit that may stop, but only instantaneously.
Evaluating Sand-Screen Performance With Sand-Retention Tests and Numerical Modeling
Authors: Carpenter Chris
Published: January 2017

This article, written by JPT Technology Editor Chris Carpenter, contains highlights of paper OTC 26434, “Evaluating Sand-Screen Performance With Improved Sand- Retention Test and Numerical Modeling,” by B. Wu, S.K. Choi, Y. Feng, R. Denke, T. Barton, C.Y. Wong, J. Boulanger, W. Yang, and S. Lim, CSIRO, and M. Zamberi, S. Shaffee, M.B. Jadid, Z. Johar, and B.B. Madon, Petronas, prepared for the 2016 Offshore Technology Conference Asia, Kuala Lumpur, 22–25 March. The paper has not been peer reviewed.

This paper presents a combined experimental and numerical-modeling study on sand-screen performance. The objective is to develop an improved methodology for optimal sand-screen-aperture selection by addressing some of the limitations present in existing sand-retention tests. A new sand-retention- test facility has been developed that incorporates a number of improvements into the design and experimental procedure.

Existing Approach to Sand-Screen-Performance Evaluation

Empirical criteria have traditionally been applied for selecting screen size on the basis of one or two parameters derived from the particle-size distribution (PSD). Because of the problems associated with the empirical criteria, the industry standard practice is to conduct laboratory sand-retention tests on screen coupons. This is particularly relevant for premium sand screens, the filter media of which are fundamentally different from those of a slotted liner or wire-wrap screen. The same mechanisms for forming stable, multiparticle bridges may or may not be applicable. In most cases, the cross-sectional path through these filter media is tortuous and 3D. Laboratory sand-retention testing is typically required to determine the effective screen opening size. There are no universal industry standards on how sand-retention testing should be performed or results interpreted. Sandscreen performance is often evaluated on the basis of two criteria: screen plugging and sand retention.

Limitations of the Existing Approach.

While the acceptance criteria for sand production and produced-particle size are well-defined and these factors are relatively straightforward to measure, screen plugging is defined differently by different investigators. There is currently a lack of measurements that can be used to accurately quantify screen plugging and screen permeability.
A Deepwater Gasfield-Development Strategy for Trinidad and Tobago
Authors: Wilson Adam
Published: January 2017

This article, written by Special Publications Editor Adam Wilson, contains highlights of paper SPE 177102, “A Deepwater Gasfield-Development Strategy for Trinidad and Tobago,” by Ayasha Nickie, Trinidad and Tobago Ministry of Energy and Energy Affairs, prepared for the 2015 SPE Latin American and Caribbean Petroleum Engineering Conference, Quito, Ecuador, 18–20 November. The paper has not been peer reviewed.

Trinidad and Tobago is the top natural-gas producer in the Caribbean, with average daily production in 2014 of 4.069 Bscf/D. With vibrant upstream, midstream, and downstream sectors, Trinidad and Tobago makes maximum use of the natural-gas value chain. Further maximization through growth in the downstream sector requires an adequate supply of natural gas in addition to the shallow-water gas fields offshore, which are currently the main supply. Because of the thriving gas sector, a large amount of infrastructure already exists that may aid with any further development.

Introduction

The Trinidad and Tobago Gas Development Model has shaped the growth of its natural-gas economy over the years, and, in 2014, the energy sector accounted for 45% of the country’s gross domestic product. Average production over the past 5 years was an estimated 4.2 Bcf/D, while average use for the same period was 3.9 Bcf/D, with liquefied natural gas (LNG) accounting for more than 50% of this consumption (Fig. 1).

With the onset of proposed additional projects in the downstream sector, additional gas use in the near future is inevitable. Although this additional capacity can emanate from the existing proved-reserves base, another source of gas could be currently unexploited deepwater basins. In the past 5 years, nine production-sharing contracts for exploration in Trinidad and Tobago’s deepwater areas were signed. If gas is discovered, first gas can be on line within 5 to 10 years of discovery. If this occurs, additional quantities of natural gas would be available for domestic, Caribbean, and Latin American markets. While deepwater gas developments have economic challenges, existing infrastructure in Trinidad and Tobago can aid development.
Guest Editorial: Assessing the Processes, Tools, and Value of Sharing and Learning From Offshore E&P Safety-Related Data
Authors: Moreau Roland
Published: January 2017

Guest editorial

In 2014, the US Department of the Interior’s Bureau of Safety and Environmental Enforcement (BSEE) approached SPE regarding a proposed collaboration opportunity to develop a voluntary industrywide near-miss data-sharing framework. The goal of this framework was envisioned as a resource to enhance the industry’s ability to capture and share key learnings from significant near-miss events with the objective of identifying and mitigating potential high-consequence risks. While the scope of this collaboration initially focused on only near misses, further discussion of the desired outcome resulted in increasing the scope to include a broader range of data that have learning value to help the industry to achieve improved safety performance. Further, in the spirit of continuous improvement, a related objective was identified to bring government and industry together to make a safe industry safer, and to enhance public confidence in the industry.

SPE and BSEE agreed to cochair a summit steering committee that included representatives from SPE, BSEE, exploration and production (E&P) operators, service companies, the US Bureau of Transportation Statistics, the Center for Offshore Safety, American Bureau of Shipping, and the International Association of Oil and Gas Producers. During the planning process of the summit, it was agreed that the scope of a data collection and reporting framework would start with the US Outer Continental Shelf (OCS). Additionally, a secondary objective was to consider how existing processes might be leveraged with an overarching objective to extend influence beyond the US OCS to align with other systems and requirements globally. In considering industry alternatives for developing a safety-data management framework, caution was advised to avoid creating an additional layer of reporting expectations over and above the current requirements by regulators and industry associations.

During the summit, Vice Admiral Brian Salerno, the director of BSEE, shared his perspective on the importance of industrywide safety-data collection and sharing. He also encouraged the E&P industry to demonstrate to the public how a safe industry could be made safer through more open data sharing.
Overcoming Technical-Assurance Challenges in Executing Parallel Megaprojects
Authors: Carpenter Chris
Published: January 2017

This article, written by JPT Technology Editor Chris Carpenter, contains highlights of paper SPE 177860, “Overcoming Technical-Assurance Challenges in Executing Parallel Megaprojects,” by Hisham Awda, Anthony Kotey, Khaled Mohamed Al-Shehhi, Malik Mohamed Shahin, and Wael Al-Madhoun, ADMA OPCO, prepared for the 2015 Abu Dhabi International Petroleum Exhibition and Conference, Abu Dhabi, 9–12 November. The paper has not been peer reviewed.

In order to meet short- and medium-term expansion goals as well as ensure a sustainable long-term future, an operator has recently embarked on several greenfield and brownfield developments. These developments include several megaprojects currently under execution, running in parallel at different phases, in split packages, and under different project teams. The objective of this paper is to share the operator’s experience and success factors in driving technical assurance during project execution.

Organizational Setup

The operator’s Discipline Engineering Division (DED) is the company’s technical authority. This division acts as the center of technical-assurance expertise in support of all of the operator’s business activities, in particular the delivery of ongoing complex-project programs.

During a project’s life cycle, the division is actively involved with the project-management team (PMT) in the following roles:

Providing a designated technical support team that works full time with the PMT as part of the project team supporting the project’s day-to- day activities

Providing additional part-time support to the PMT through a pool of shared subject-matter experts (SMEs) as required

Providing additional support to the project-management consultant (PMC) as required

Providing the overall project program with management-level support in the role of the company’s overall technical authority Fig. 1 outlines the roles in a typical project setup.

Functions

DED roles are fulfilled by adopting a framework of proactive involvement and support throughout the full project life cycle at five different project phases: Assess, Select, Define, Execute, and Operate.