Relevant bibliographies by topics / Oil and gas development projects

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  1. Journal articles
  2. Dissertations / Theses
  3. Books
  4. Book chapters
  5. Conference papers
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Academic literature on the topic 'Oil and gas development projects'

Author: Grafiati
Published: 18 May 2024

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Journal articles on the topic "Oil and gas development projects"

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O'Brien, Geoff, Monica Campi, and Graeme Bethune. "2013 PESA production and development review." APPEA Journal 54, no. 1 (2014): 451. http://dx.doi.org/10.1071/aj13044.

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The boom in Australian oil and gas development continued in 2013, with record overall investment of $60 billion. This investment resulted from spending on the seven LNG projects under development, together with that on numerous other oil and gas developments. These projects are expected to collectively contribute up to 665 million barrels of oil equivalent (MMboe) to Australia’s oil and gas production, which totaled 513.8 MMboe in 2013. LNG, presently Australia’s seventh largest export, is likely to soon rival the nation’s largest export, iron ore. By the end of 2013, three of the LNG projects under construction—Gorgon, Queensland Curtis LNG (QCLNG) and Gladstone LNG (GLNG)—were more than 70% complete; first LNG will be before the end of 2014 for QCLNG and in 2015 for Gorgon, GLNG and Australia Pacific LNG (APLNG). The other three LNG projects—Wheatstone, Prelude and Ichthys—are close behind. These new LNG projects follow Pluto, Australia’s third LNG project, which commenced production in 2012. A full year of production from Pluto drove increased gas production in 2013. Woodside also completed the North Rankin redevelopment and continued development of the Greater Western Flank, both of which will extend the life of the North West Shelf (NWS) project. A number of other projects also commenced production. In the Carnarvon Basin, oil production began at Santos’s Fletcher-Finucane Field, and at BHP Billiton’s Macedon project, domestic gas production started. In the Timor Sea, PTTEP’s Montara Field began production of oil. In Victoria, the ExxonMobil Kipper-Turrum-Tuna project came online, with the production of gas from Tuna and oil from Turrum. Production of gas from Origin Energy’s Geographe Field (as part of the Otway Gas Project) commenced in mid-2013. Onshore oil production grew in 2013, with the Cooper-Eromanga Basin now producing more oil than any other onshore Australian basin. A major effort is underway to increase production from the western flank oil trend and to develop both the conventional and unconventional gas fields in the Cooper Basin. Spending on the development of new projects probably peaked in 2013 and there is growing concern about a dearth of future projects, with expansion of existing LNG projects and development of new projects being pushed back due to a combination of increased costs and growing international competition. There are also ongoing industry concerns about impediments to onshore gas exploration and development generally.
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Willetts, Jim. "Production and development review 2007." APPEA Journal 48, no. 1 (2008): 423. http://dx.doi.org/10.1071/aj07030.

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Australian petroleum production was close to record levels in 2007 with higher oil production and expansion of domestic gas, LNG and coal seam gas production. Growth in coal seam gas production has reached the point where it is not only providing a significant supply source for domestic gas and power station projects, but is proposed as the source of supply to no less than four potential LNG export plants in Queensland. Five new oil and gas developments came on stream during the year. Four final investment decisions were taken on major projects, the largest being the Pluto project in the Carnarvon Basin. The pipeline of committed and potential projects now includes about 25 significant petroleum projects with a combined value of over $100 billion. Together these have the potential to significantly increase Australian production in the next five to ten years, primarily through growing gas production. In the near term significant new oil projects carry the prospect of higher oil production in 2008. Cost estimates for new projects continued to escalate sharply and skills shortages in all parts of the project delivery chain threaten the ability to deliver all of the projects as contemplated.
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Humphreys, Geoff. "PESA production and development review 2009." APPEA Journal 50, no. 1 (2010): 121. http://dx.doi.org/10.1071/aj09009.

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Australian hydrocarbon production reached record levels in 2009 due to strong growth in production of LNG from the North West Shelf Venture. Domestic gas production also reached record levels. Coal seam gas production continued to grow, with the continuing development of existing fields and the development of the Kenya and Talinga projects in Queensland. Two new conventional gas projects also came into production: Blacktip in the Timor Sea and Longtom in the Gippsland Basin. However oil production was below that in the previous year, reflecting natural field decline and the absence of large scale projects reaching production. The project sanction highlight of the year was the final investment decision on the $43 billion Gorgon LNG project. This project will comprise three LNG trains with total capacity of 15 million tonnes per annum plus a domestic gas plant. The first gas from this project is planned for 2014. Eight other potential LNG projects are in various stages of front end engineering and design, most targeting final investment decisions in 2010 or 2011. The pipeline of committed and potential LNG projects has a combined value estimated to be well over $100 billion. These projects have the potential to significantly increase Australian LNG production over the next five to ten years. In the near term the start-up of the Van Gogh, Pyrenees and Turrum oil projects are expected to provide some respite from the decline in Australian oil production. Cost estimates for new projects are again escalating and skills shortages in all parts of the project delivery chain threaten the ability to deliver all of the projects under consideration.
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Zhang, Muzhen, Ailin Jia, Zhanxiang Lei, and Gang Lei. "A Comprehensive Asset Evaluation Method for Oil and Gas Projects." Processes 11, no. 8 (August 9, 2023): 2398. http://dx.doi.org/10.3390/pr11082398.

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The rapid and accurate evaluation of oil and gas assets, specifically for new development projects, poses a significant challenge due to the various project types, limited data availability, brief periods for assessment and decision making, and constraints arising from varying contractual and taxation conditions, political stability, and societal factors. This study leverages the grading standards of the evaluation index system for new oil and gas field development projects, along with relevant mathematical theories and methods for project evaluation and optimization. We developed an asset evaluation approach for new oil and gas projects by analyzing the assets of six new oil and gas field development projects in Brazil. This analysis resulted in the grading and ranking of new projects, and we tested and demonstrated four asset optimization techniques. After a comparative analysis with conventional evaluation results, we established an oil and gas project asset optimization approach centered on the cloud model comprehensive evaluation and linear weighted ranking, exhibiting Kendall’s tau coefficient of 0.8667 with conventional methods. The findings suggest that the combination of the cloud model comprehensive evaluation method with the linear weighted ranking method can facilitate asset optimization for oil and gas field development projects, meeting the practical needs for fast selection among various new projects. Furthermore, this research offers a technical and theoretical foundation for rapid evaluation and decision making regarding new assets.
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Marin, Evgenii A., Tatiana V. Ponomarenko, Natalia V. Vasilenko, and Sergey G. Galevskiy. "Economic evaluation of projects for development of raw hydrocarbons fields in the conditions of the northern production areas using binary and reverting discounting." Север и рынок: формирование экономического порядка 25, no. 3/2022 (September 29, 2022): 144–57. http://dx.doi.org/10.37614/2220-802x.3.2022.77.010.

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The conversion from the development of large deposits to unconventional, small and Arctic deposits of hydrocarbon raw materials in the Russian requires oil and gas companies improving the quality of the economic justification of projects, including cost-effectively recoverable reserves. For this reason, the development of the discounted cash flow (DCF) method for economic evaluation of oil and gas projects is required. The purpose of the study was to develop a methodological approach to the economic evaluation of oil and gas projects. The disadvantages of the DCF model in the economic evaluation of oil and gas field development projects are analyzed, a comparative analysis of project evaluation methods through the use of binary and reverting discounting models is performed. The authors justified the choice of a risk-free discount rate for project outflows and dynamically changing values of discount rates for project cash inflows for the evaluation of oil and gas projects, taking into account their identified features. The application of the developed methodological approach, both at the pre-project phase and during the operation of the field, will allow oil and gas companies to justify the magnitude of commercially exploitable reserves and indicators of the economic efficiency of the project due to more correct risk accounting. The developed methodological approach has been approved on the example of the Novoportovskoye field development project.
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Cherepovitsyn, Alexey, Anna Tsvetkova, and Nadejda Komendantova. "Approaches to Assessing the Strategic Sustainability of High-Risk Offshore Oil and Gas Projects." Journal of Marine Science and Engineering 8, no. 12 (December 6, 2020): 995. http://dx.doi.org/10.3390/jmse8120995.

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In the face of today’s global challenges, oil and gas companies must define long-term priorities and opportunities in implementing complex Arctic offshore projects, taking into account environmental, economic, technological and social aspects. In this regard, ensuring strategic sustainability is the basis for long-term development. The aim of the study is to analyze existing approaches to the concept of “strategic sustainability” of an offshore Arctic oil and gas project and to develop a methodological approach to assessing the strategic sustainability of offshore oil and gas projects. In the theoretical part of the study, the approaches to defining strategic sustainability were reviewed, and their classification was completed, and the most appropriate definition of strategic sustainability for an offshore oil and gas project was chosen. The method of hierarchy analysis was used for strategic sustainability assessment. Specific criteria have been proposed to reflect the technical, geological, investment, social and environmental characteristics important to the offshore oil and gas project. The strategic sustainability of 5 offshore oil and gas projects was analyzed using an expert survey as part of the hierarchy analysis method. Recommendations were made on the development of an offshore project management system to facilitate the emergence of new criteria and improve the quality of the strategic sustainability assessment of offshore projects in the Arctic.
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Bethune, Graeme. "Australian petroleum production and development 2018." APPEA Journal 59, no. 2 (2019): 482. http://dx.doi.org/10.1071/aj18285.

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This Petroleum Exploration Society of Australia review looks in detail at the trends and highlights for oil and gas production and development both onshore and offshore Australia during 2018. Total petroleum production climbed strongly for the third consecutive year, driven by LNG. A highlight is the start-up of the INPEX Ichthys project. Production is set for further growth in 2019 with the ramp-up of this project and the start-up of Shell’s Prelude floating LNG project. Prelude and Ichthys are the last projects to be commissioned in a wave of seven new LNG projects that are making Australia the world’s largest LNG exporter and a crucial supplier of gas to Asia, including the largest source of LNG for Japan and China and the second-largest source for South Korea. By contrast, Australian oil production continued to fall rapidly and is now easily surpassed by rising condensate production from new LNG projects. There were stark contrasts between domestic gas on the west and east coasts. On the west coast, prices remain low and supply relatively plentiful. The east coast domestic market was tighter and LNG producers responded by diverting gas supplies to the domestic market. This paper canvasses these trends and makes conclusions about the condition of the oil and gas industry in Australia. This paper relies primarily on production and reserves data compiled by EnergyQuest and published in its EnergyQuarterly reports.
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Nadrus, Inas, Valery Anshin, and Igor Demkin. "One Method to Identify the Real Options in the Investment Project." Scientific Research and Development. Russian Journal of Project Management 8, no. 3 (December 18, 2019): 35–44. http://dx.doi.org/10.12737/2587-6279-2019-35-44.

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The present article describes a research that examines the sources of flexibility in the investment projects in the oil and gas industry using multiple case studies of several oil and gas projects. More precisely, the study is concerned with revealing uncertainties that give rise to real options. Ultimately, the methodology for real options identification in the exploration & development type of investment projects of the oil and gas industry is proposed. It is anticipated that the results might help to bring certain improvements into the existing managerial conception of using real options for investment project evaluation considering the specific nature of investment projects in the oil and gas industry.
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McMahon, Xavier T., and Jake D. Williams. "'Lawfare' in the oil and gas industry." APPEA Journal 59, no. 2 (2019): 651. http://dx.doi.org/10.1071/aj18251.

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There is a growing concern within the resources industry about activists’ use of the legal system to disrupt and delay major projects. Currently, referred to by many as ‘lawfare’, the tactic is not new. However, recent challenges to high profile cases, such as the Adani Carmichael Coal Project, has brought renewed focus to the tactics being used by activists to further their agendas, and a perception at least that the risk to the industry is ever increasing. This paper looks at trends and novel developments in national and international environmental law, and considers what implications this may have for the development of oil and gas projects in Australia.
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������ and Igor Demkin. "Estimation of Company Participation Cost in International Oil & Gas Projects." Russian Journal of Project Management 2, no. 1 (March 29, 2013): 0. http://dx.doi.org/10.12737/280.

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The competition aggravation in the world oil and gas markets forces the companies to realize projects not only within the country, but also abroad for ensuring competitive advantage. When elaborating of strategies of development and investment programs the oil and gas companies face the need of cost estimation related to participation in international projects. In this article the methodology developed by authors of cost estimation related to participation in international oil and gas projects is presented. Approbation was carried out on the project of Wheatstone LNG production and supply. Application of research results will allow the oil and gas companies to carry out the efficiency assessment of participation in the international projects, and also to reduce time and to increase scientific validity of development of strategy and investment programs.
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Dissertations / Theses on the topic "Oil and gas development projects"

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Kilani, Meriam. "Multiple product-project decisions coordination support : application to oil and gas development projects." Electronic Thesis or Diss., université Paris-Saclay, 2023. http://www.theses.fr/2023UPAST027.

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Le défi majeur abordé dans cette recherche concerne la coordination de multiples décisions interdépendantes qui doivent être prises lors du projet, qu'elles soient techniques, financières ou contractuelles. Interdépendance signifie que prendre une décision sans tenir compte des impacts sur les autres décisions peut entraîner une sous-performance, voire des impasses, des itérations et des reprises. Pour surmonter ce défi, un processus de prise simultanée de décisions multiples a été proposé, en trois blocs : 1/ modélisation du réseau de décisions et formulation du problème multi-décisionnel ; 2/ structuration du problème pour proposer des scénarios pertinents et plausibles assemblés à partir d'alternatives de décisions élémentaires ; 3/ résolution du problème par la sélection et la recommandation de scénarios. La construction du processus de prise de décisions multiples est basée sur des possibilités diverses pour chaque bloc. Le décideur sélectionne parmi un ensemble de choix possibles pour adapter le processus décisionnel à son contexte précis. Pour le bloc 1, nous avons d'abord construit un réseau global qui modélise les décisions étudiées et les interdépendances qu'elles peuvent avoir avec d'autres décisions. Nous avons ensuite indiqué que les graphes et les matrices peuvent être utilisés pour répondre à ce besoin. Les deux méthodes permettent d'inclure toutes les décisions et interdépendances du réseau de décision dans un seul modèle, chacune d'entre elles ayant ses avantages et inconvénients, avec une sorte de complémentarité. Ensuite, pour formuler le problème local de multi-décision, deux approches de clustering basées sur les interactions sont proposées : l'approche descendante (considérant les interdépendances des décisions) et l'approche ascendante (avec un regroupement supplémentaire des décisions basé sur la date d'échéance). Ces deux approches aident à délimiter le périmètre sur un ensemble spécifique de décisions, étant donné qu'il peut être difficile de considérer tout le réseau de décisions en même temps. Dans le bloc 2, pour structurer le problème, deux méthodes basées sur des matrices et une autre basée sur des graphes ont été proposées. Ces méthodes offrent la possibilité de générer des scénarios en considérant les critères de compatibilité et de performance, soit séquentiellement (analyse morphologique), soit simultanément (QFD), soit de manière hybride (exploration de graphe). Pour les deux méthodes basées sur les matrices, un algorithme a été proposé pour faciliter l'identification de scénarios plausibles. Quant à la méthode basée sur les graphes, une heuristique plus légère peut être appliquée en temps réel lors d'une réunion de décision. Enfin, pour résoudre le problème, plusieurs méthodes MCDA ont été répertoriées dans le bloc 3 pour évaluer et sélectionner un scénario recommandé : méthodes d'évaluation absolue, méthodes de comparaison relative par paire, et méthodes de comparaison relative à des points de référence. Selon les acteurs industriels, un tel processus pourrait améliorer les mécanismes de coordination entre les décisions majeures de leurs projets. Même si les décisions sont interdépendantes, elles ne sont pas souvent considérées comme telles, et le processus que nous proposons permet (selon eux) d'avoir une meilleure vision des décisions à prendre ensemble et des conséquences des choix. Une étude de cas fictive, inspirée de projets réels passés, a été utilisée pour illustrer le processus de coordination multi-décision proposé. Nous sommes convaincus que notre recherche fournira une base solide pour d'autres études portant sur la coordination de décisions multiples et interdépendantes dans le cadre de projets complexes, même si certaines perspectives académiques et industrielles doivent être abordées
The major challenge addressed in this research concerns the coordination of the multiple interdependent decisions that must be made during the project, either technical, financial, or contractual. Interdependence means that making one decision without considering the impacts for other decisions may imply some underperformance, or even dead ends, iterations, and rework.To overcome this challenge, a more adaptable multi-decision-making process has been proposed, consisting of three blocks: 1/ modeling the decision network and formulating the multi-decision problem; 2/ structuring the problem to propose relevant and plausible scenarios assembled from elementary decision alternatives; 3/ solving the problem by selecting and recommending scenarios.Building the multi-decision-making process is based on multiple possibilities for each block. The decision-maker selects from a set of possible choices to adapt the decision-making process to the precise context.For block #1, we have first articulated the need to build a global decision network that models the decisions under study and the interdependencies they may have with other decisions. We have then argued that graphs and matrices can be used to fulfill this need. Both methods allow to include all decisions and interdependencies of the decision network in one single model, each of them having its advantages and drawbacks, with a kind of complementarity.Then, to formulate the local multi-decision problem, two interactions-based clustering approaches are proposed: the top-down approach (considering decision interdependencies) and the bottom-up approach (with an additional due date-based grouping of decisions). Both help to delineate the focus of decision makers on a specific set of decisions, since considering the whole network of decisions at the same time can be challenging.In block #2, to structure the problem, two matrix-based and one graph-based methods have been proposed. These methods offer the possibility to generate possible scenarios considering compatibility and performance criteria, either sequentially (morphological analysis), simultaneously (QFD), or with a hybrid way (graph exploration). For the two matrix-based methods, an algorithm was proposed to facilitate the identification of plausible scenarios. As for the graph-based method, a lighter heuristic can be applied on live during a decision meeting.Finally, to solve the problem in block #3, several MCDA methods have been listed for evaluating and selecting a recommended scenario: absolute compensatory methods, relative pairwise comparison methods, and relative comparison to reference point methods.According to industrial actors, such a process could improve coordination mechanisms between the major decisions of their projects. Even though decisions were interdependent, they were not often considered as such, and our proposed process permits (according to them) to have a better vision of the decisions to be made together and of the consequences of the choices. A fictitious case study, inspired by real past projects, was used to illustrate the proposed multi-decision coordination process.We are convinced that our research will provide a solid basis for further studies on the coordination of multiple interdependent decisions in complex projects, although there are academic and industrial perspectives that need to be tackled
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Akoh, Emmanuel Inalegwu. "Barriers to public participation in developmental projects : a Nigerian community perspective (case study of the Gbaran-Ubie oil and gas project)." Thesis, Rhodes University, 2013. http://hdl.handle.net/10962/d1001869.

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This research paper is broken up into three sections, namely an evaluation report, a literature review and research methodology. The evaluation report section is the assessment of the current state of change readiness within the Eskom Contact Centre’s based upon what the literature on change readiness prescribes. The timing of the change readiness assessment is just prior to significant organisational change. The organisational change that was about to be initiated by the organisation was initiated from the boardroom of the most senior echelons of the organisation, and was directed in a top down approach, being a strategic organisational change. The change is deemed to be critical to the organisation being able to meet its long term strategic and sustainability objectives. A critical examination of the literature explored the meaning of change readiness, the importance of it and explained the consequences for organisations that commit to transformational agendas without being ready. Key concepts such as such resistance to change and organisational inertia are described and differentiated from change readiness. The ADKAR change model and its change readiness assessment instrument were used due to the organisations preference for the model. The ADKAR model formed the framework for the analyses of the data, the discussion of the results and the recommendations to the organisation. The research conducted was quantitative in nature; a questionnaire was distributed to the employees of the seven Eskom Contact centre sites around the country through an email. A slightly modified version of the ADKAR change readiness questionnaire was sent via email with an on-line questionnaire link on it; and questions on individual readiness for change were used to assess the level of readiness of the employees. Most of the descriptive and inferential statistics were analysed with the use of Excel (version, 2010), with Factor Analysis being done in Statistica. The results of the research showed that: [iii] - The factors as proposed by the ADKAR change readiness assessment questionnaire (i.e. Awareness, Desire, Knowledge, Ability and Reinforcement) are not different enough to be considered as independent factors for this data set. Based on factor analysis, the factors were subsequently amended from five to three, namely Readiness, Opportunity Realisation and Uncertainty. - The Contact Centre employees were somewhat ready for change. - The Contact Centres needed to focus on all amended ADKAR factors in order to improve the readiness of the department. - The readiness levels in response to the roll out were more or less uniform. The study shows that given Eskom’s preference for the ADKAR model, future research within Eskom should therefore be conducted more circumspectly with respect to ascertaining the validity of the ADKAR factors. The study also makes mention that future work and/or research will need to be conducted, specifically on the readiness of the organisation itself, in order to improve the probability of transformational success. The ADKAR assessment is a people focused assessment and therefore focuses only on the readiness of the individual. Factors such as the adequacy of the current state of resources within the organisation, which incorporate aspects such as infrastructure, technology and staffing, will also need to be assessed to make a more holistic statement of change readiness. A concise review of the literature is incorporated into the Evaluation Report of Section 1 to underpin the study. In Section 2 a more extensive review of the literature is presented. Similarly, the design of the research is discussed in more detail in Section 3 to both describe and justify the appropriateness of the research methodology, and to give a detailed account of the way in which the research was carried out.
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Mohebbi, Amir Hassan, and Ngadhnjim Bislimi. "Project Risk Management : Methodology Development for Engineering, Procurement and Construction Projects - A Case Study in the Oil and Gas Industry." Thesis, Karlstads universitet, Fakulteten för ekonomi, kommunikation och IT, 2013. http://urn.kb.se/resolve?urn=urn:nbn:se:kau:diva-29142.

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This thesis studies the overall parameters affecting projects’ risks and analyze different methodologies of project risk management in order to narrow down and develop a customized methodology applicable for Engineering, Procurement and Construction (EPC) projects in the oil and gas industry. To approach this goal, Bidboland II Gas Treating Plant project was selected as an appropriate case study. This case project has been analyzed by combining various risk management methodologies, and based on this analysis a new methodology was suggested to the company for risk management. Additionally, necessary changes in the organization have been proposed to handle the project risk issues in different levels with higher performance. The developed methodology can be applicable for other companies involved in EPC projects.
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Nwete, Bede. "The role of soft law in oil and gas project development in developing countries : a study of how this impacts social-legal risks management in the oil and gas industry." Thesis, University of Aberdeen, 2017. http://digitool.abdn.ac.uk:80/webclient/DeliveryManager?pid=234033.

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Afidegnon, Kodjo Galevissi. "Success Factors for Power Project Development Businesses in Sub-Saharan Africa." ScholarWorks, 2019. https://scholarworks.waldenu.edu/dissertations/6502.

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Despite the financing gap in the sub-Saharan Africa power sector, private investors struggle to capitalize on the opportunity because of the high failure rate of power project development companies. Using the conceptual framework of the behavioral finance theory, this multiple case study was conducted to explore the strategies used by executives of 4 companies in sub-Saharan Africa who successfully developed power projects within the last 5 years. Data were collected from semistructured interviews and a review of government and institutions' websites. Yin's 5-phased cycle for analyzing case studies provided the guidelines for data analysis. Three themes emerged from data analysis: market knowledge, stakeholder alignment, and commercial viability. Findings revealed strategies that current and aspiring power project development company executives may use as a guide to mitigate business failure risks. Implications of these findings for positive social change include the potential to increase the power generation capacity in sub-Saharan Africa and provide electricity to many of the 620 million Africans who currently lack access. Implications also include poverty alleviation and economic growth through creation of successful power project development companies.
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Al-Saffar, Ali. "An investigation into the project scope of work role and characteristics, and its development process enablers and barriers in the Oil and Gas Sector : a comparative case study, Saudi Arabia." Thesis, University of Manchester, 2018. https://www.research.manchester.ac.uk/portal/en/theses/an-investigation-into-the-project-scope-of-work-role-and-characteristics-and-its-development-process-enablers-and-barriers-in-the-oil-and-gas-sector-a-comparative-case-study-saudi-arabia(4bf3c4d8-cfc8-4061-b9e5-f95fb45b5ee3).html.

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A critical issue that faces the Saudi Arabia Oil and Gas Sector (OGS)'s projects is the high level of uncertainty in the successful delivery of those projects. That high level of uncertainty makes it vital to monitor and control project performance for limiting financial losses, avoiding cost overruns, and improving predictability. One of the fundamental tools that sets the framework for project performance is the project Scope of Work (SOW). Having an effective project SOW at the front end the project is challenging for project practitioners and is an issue that needs to be addressed; as its development process and output can significantly affect the later stages of the project life cycle. The aim of this study was to develop a clearer understanding of the project SOW role in a project development and to make practical recommendations for its improvement by investigating project team members' perceptions of the SOW development process in two Saudi Arabian Oil and Gas companies. This research adopts a qualitative approach, a case study strategy and focus group discussions to collect primary data. The results suggested that the project SOW development process is the foundation for another twelve key project management processes that need to be considered in order to successfully complete a project On Scope, On Time, On Cost and On Strategy. To be considered effective, the project SOW should have the following four characteristics of: formality, usefulness, effective content elements and effective language quality. In addition, the project SOW should support effective decision making, risk management, project planning and project monitoring and control. The results show that the project SOW in Saudi Arabia OGS is developed in several phases as part of Front-End Loading (FEL) development and final project SOW is developed and approved at the end of the 2nd phase of FEL (FEL-2). It was found that there are eleven key enablers, such as clear vision, targets, and objectives; effective stakeholders' engagement; and effective assurance review process, for producing an effective project SOW. While eleven key barriers for producing an effective SOW were identified such as: absence of reward system; insufficient training programs; and insufficient budget. Therefore, enhancing the key enablers and overcoming the barriers may facilitated improvements in the project SOW development process. This study recommends that companies need to pay closer attention to the design of the temporary organisation and accordingly set their strategy, structure, process, rewards and people. The researcher details some implications, acknowledges some limitations and provides recommendations for future research in this area.
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Ghadhban, Zaid T. "Design of a stand alone fully integrated communications, monitoring and control system for a novel remote sub-sea gas facility." Curtin University of Technology, Faculty of Engineering, Department of Chemical Engineering, 2008. http://espace.library.curtin.edu.au:80/R/?func=dbin-jump-full&object_id=120520.

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The growing demand for hydrocarbon fluids, and the future expectation of insufficient onshore reserves, is driving the exploration and development of off-shore oil and gas fields. A significantly increasing number of the new fields are situated in deep water, placing significant constraints on the application of conventional platform (sea surface) systems. This has, by necessity, generated the rapid growth of sub-sea processing technology.
An integral part of a novel sub-sea natural gas dehydration project is the need to design and develop a communications, monitor and control system that is extremely reliable within a harsh marine environment. The off shore gas gathering and processing facility will be unmanned, therefore the entire ongoing operation of the sub-sea facility, and any sea surface equipment, will be dependent on the proper functioning of the communication system. System redundancy and low power consumption are also important issues.
The continuous bi-directional transmission of information between the field and shore-based control centres, together with the complexity of any maintenance / repair missions requires an extremely highly reliable system. The prospect of false alarms must be maintained at an absolute minimum.
Within this thesis the history and development of ocean based communications up to current state-of-the art technology is reviewed. Based on the unique and demanding requirements of the sub-sea gas processing facility, detailed recommendations are made for both a primary and back-up communication systems that meet the given criteria of being robust and having very low power requirements.
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Alonge, Funmilayo Ronke. "Financing oil and gas projects in Nigeria." Master's thesis, University of Cape Town, 2014. http://hdl.handle.net/11427/9158.

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Includes bibliographical references.
Oil and gas is a major source of energy worldwide. Therefore its significance for Nigeria as a major producer cannot be understated. Notwithstanding the huge revenue derived from oil and gas, its contribution to the Gross Domestic Product (GDP) is minimal. This can be ascribed to the fact that there has been minimal indigenous participation in oil and gas projects as this has often been undertaken by the International Oil Companies (IOCs). To address this, the Federal Government awarded marginal fields and oil blocks to independent indigenous oil companies and enacted the Nigerian Oil and Gas Industry Content Development Act in 2010. This has been of great benefit to indigenous participation. However, these indigenous companies often encounter a major problem in accessing finance for their projects. This dissertation examines the challenges to financing faced by the independent indigenous oil companies and how project financing will be the best means of financing a project by these companies.
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Souza, Dayse da Mata Oliveira. "Sistemas de medi??o de desempenho para projetos de PD&I no Setor de Petr?leo e G?s Natural." Universidade Federal do Rio Grande do Norte, 2014. http://repositorio.ufrn.br:8080/jspui/handle/123456789/13031.

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Made available in DSpace on 2014-12-17T14:09:17Z (GMT). No. of bitstreams: 1 DayseMOS_TESE.pdf: 4185831 bytes, checksum: 7ffe8ba649c7a5670d11523f5cc43976 (MD5) Previous issue date: 2014-01-31
Organizations are seeking new ideas, tools and methods aiming to improve management process and performance. On the other hand, system performance measurement needs to portray organizational changes and provide managers with a set of true and more appropriate information for the decision-making process. This work aims to propose a performance measurement system in the academic field regarding Research, Development and Innovation (RDI) in the oil and gas industry. The research performed a bibliographic review in a descriptive exploratory manner. A field research was conducted with an expert focus group in order to gather new indicators. As for the validation of these indicators, a survey with experienced professional was also realized. The research surveyed four segments in and outside of the Federal University of Rio Grande do Norte-Brazil such as oil and gas project coordinators, staff at Academic Planning Offices, FUNPEC employees as well as coordinators from Petrobr?s. The performance measuring system created from this study features three interrelated performance indicators pointed out as: process indicators, outcome indicators and global indicators. The proposal includes performance indicators that seek to establish more appropriate strategies for effective institution management. It might help policy making of university-industry interaction policies
Cada vez mais as organiza??es est?o ? procura de novas id?ias, novas ferramentas e novos m?todos que as ap?iem no aprimoramento do seu processo de gest?o e assim, melhorar seu desempenho. Por conseguinte, os sistemas de medi??o de desempenho precisam retratar as mudan?as nas organiza??es proporcionando aos seus gestores um conjunto de informa??es verdadeiras e mais adequadas ? tomada de decis?o. O objetivo deste trabalho ? propor um sistema de medi??o de desempenho para os projetos de PD&I no setor de petr?leo e g?s natural para universidades. A pesquisa foi realizada utilizando-se dos seguintes procedimentos: uma revis?o bibliogr?fica com um car?ter explorat?rio-descritivo, acompanhada da pesquisa de campo, a realiza??o de focus group com especialistas para o levantamento de novos indicadores e um survey com profissionais experientes envolvidos na execu??o de projetos dessa natureza, com a finalidade de valida??o dos indicadores. Foram pesquisados quatro segmentos por meio de coordenadores de projetos de petr?leo e g?s natural da UFRN, funcion?rios da Pr?-Reitoria de Planejamento, funcion?rios da FUNPEC e coordenadores da Petrobras. O sistema de medi??o de desempenho gerado a partir deste estudo apresenta em sua estrutura tr?s grupos de indicadores de desempenho inter-relacionados: indicadores de processo, indicadores de resultado e indicadores globais. A proposta inclui indicadores de desempenho que procuram estabelecer uma estrat?gia mais adequada para uma gest?o eficaz das institui??es e pode contribuir para auxiliar as pol?ticas de intera??o universidade-empresa
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Al-Thani, Faisal F. J. "Comprehensive financial model for oil and gas field projects in Qatar." Thesis, University of Leeds, 2002. http://etheses.whiterose.ac.uk/3891/.

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Project finance is essentially the raising of finance for a new project, secured against future revenues rather than an existing corporate balance sheet or other existing assets. The completion of the project, its successful and profitable operations, is therefore the key concern for all lenders and investors. This means that all the elements influencing the costs, revenues and returns from the project are of interest when determining the finance structure. Existing financial models were not designed to cover all these essential aspects. Analysis of the projected cash flows for the deal is therefore essential, from financial close to the end of the concession or plant life, under a range of assumptions. A case study is developed using Qatar's North Field, RasGas (Ras Laffan Liquefied Gas Company) data for this purpose. This is a multi-billion dollar company set up to develop the Gas Extracting and Utilisation Project in Qatar. The projects cannot be financed from the present country revenue, and therefore, external project financing is required. Decisions have to be made regarding the amount to be raised, acceptable securities, criteria for a Target Capital Structure for all new Gas/Oil Extraction/Utilisation Projects and other related decisions. The thesis verifies and validates a unique, innovative, specific, accurate and cost saving Comprehensive Financial Model for the oil and gas industry in Qatar, to facilitate the evaluation of new projects in the future.
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Books on the topic "Oil and gas development projects"

1

De Bauw, R., E. Millich, J. P. Joulia, D. Van Asselt, and J. W. Bronkhorst. European Communities Oil and Gas Technological Development Projects. Dordrecht: Springer Netherlands, 1987. http://dx.doi.org/10.1007/978-94-009-3247-0.

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P, Joulia J., and Commission of the European Communities., eds. European communities oil and gas technological development projects: Fourth status report. London: Graham & Trotman for the Commission of the European Communities, 1990.

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Lachlan, Taylor John, Warner E. Waide, and Practising Law Institute, eds. Project financing in emerging markets, 2000: Successful development of power, oil and gas, mining, telecommunications and transportation projects. New York: Practising Law Institute, 2000.

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1945-, Bott Robert, and Petroleum Communication Foundation, eds. Our petroleum challenge: Exploring Canada's oil and gas industry. 6th ed. Calgary, AB: Petroleum Communication Foundation, 1999.

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Bott, Robert. Our petroleum challenge: Exploring Canada's oil and gas industry. 6th ed. Calgary: Petroleum Communication Foundation, 1999.

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Office, United States Bureau of Land Management Rock Springs Field. Environmental assessment for the Vermillion Basin natural gas exploration and development project. Rock Springs, Wyo: The Office, 2000.

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United States. Bureau of Land Management. Rock Springs Field Office. Environmental assessment for the Vermillion Basin natural gas exploration and development project. Rock Springs, Wyo: The Office, 2000.

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United States. Bureau of Land Management. Alaska State Office. Greater Mooses Tooth 2 oil and gas development project: Joint record of decision and permit evaluation. Anchorage, Alaska: U.S. Department of the Interior, Bureau of Land Management, Alaska State Office, 2018.

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limited, Atlantic Consulting Economists, and Gardner Consulting Economists Limited, eds. Comparison of major construction projects and offshore hydrocarbon developments in Atlantic Canada. [Toronto, Ont.]: Gardner Pinfold Consulting Economists, 1985.

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United States. Bureau of Land Management. Pinedale Field Office., United States. Army. Corps of Engineers., and United States Forest Service, eds. Final environmental impact statement for the Pinedale Anticline Oil and Gas Exploration and Development Project, Sublette County, Wyoming. Pinedale, Wyo: U.S. Dept. of the Interior, Bureau of Land Mangement, Wyoming State Office, 2000.

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Book chapters on the topic "Oil and gas development projects"

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De Bauw, R., E. Millich, J. P. Joulia, D. Van Asselt, and J. W. Bronkhorst. "Natural Gas Technology." In European Communities Oil and Gas Technological Development Projects, 313–22. Dordrecht: Springer Netherlands, 1987. http://dx.doi.org/10.1007/978-94-009-3247-0_9.

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De Bauw, R., E. Millich, J. P. Joulia, D. Van Asselt, and J. W. Bronkhorst. "Geophysics and Prospecting." In European Communities Oil and Gas Technological Development Projects, 1–56. Dordrecht: Springer Netherlands, 1987. http://dx.doi.org/10.1007/978-94-009-3247-0_1.

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De Bauw, R., E. Millich, J. P. Joulia, D. Van Asselt, and J. W. Bronkhorst. "Energy Sources." In European Communities Oil and Gas Technological Development Projects, 323–31. Dordrecht: Springer Netherlands, 1987. http://dx.doi.org/10.1007/978-94-009-3247-0_10.

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De Bauw, R., E. Millich, J. P. Joulia, D. Van Asselt, and J. W. Bronkhorst. "Storage." In European Communities Oil and Gas Technological Development Projects, 333–42. Dordrecht: Springer Netherlands, 1987. http://dx.doi.org/10.1007/978-94-009-3247-0_11.

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De Bauw, R., E. Millich, J. P. Joulia, D. Van Asselt, and J. W. Bronkhorst. "Miscellaneous." In European Communities Oil and Gas Technological Development Projects, 343–82. Dordrecht: Springer Netherlands, 1987. http://dx.doi.org/10.1007/978-94-009-3247-0_12.

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De Bauw, R., E. Millich, J. P. Joulia, D. Van Asselt, and J. W. Bronkhorst. "Drilling." In European Communities Oil and Gas Technological Development Projects, 57–78. Dordrecht: Springer Netherlands, 1987. http://dx.doi.org/10.1007/978-94-009-3247-0_2.

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De Bauw, R., E. Millich, J. P. Joulia, D. Van Asselt, and J. W. Bronkhorst. "Production Systems." In European Communities Oil and Gas Technological Development Projects, 79–181. Dordrecht: Springer Netherlands, 1987. http://dx.doi.org/10.1007/978-94-009-3247-0_3.

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De Bauw, R., E. Millich, J. P. Joulia, D. Van Asselt, and J. W. Bronkhorst. "Secondary and Enhanced Recovery." In European Communities Oil and Gas Technological Development Projects, 183–244. Dordrecht: Springer Netherlands, 1987. http://dx.doi.org/10.1007/978-94-009-3247-0_4.

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De Bauw, R., E. Millich, J. P. Joulia, D. Van Asselt, and J. W. Bronkhorst. "Environmental Influence on Offshore." In European Communities Oil and Gas Technological Development Projects, 245–52. Dordrecht: Springer Netherlands, 1987. http://dx.doi.org/10.1007/978-94-009-3247-0_5.

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De Bauw, R., E. Millich, J. P. Joulia, D. Van Asselt, and J. W. Bronkhorst. "Auxiliary Ships and Submersibles." In European Communities Oil and Gas Technological Development Projects, 253–69. Dordrecht: Springer Netherlands, 1987. http://dx.doi.org/10.1007/978-94-009-3247-0_6.

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Conference papers on the topic "Oil and gas development projects"

1

Praveen Sam, Samraj, and Avinash Airani. "Enabling New Field Development Projects for a Digital Future." In SPE Oil and Gas India Conference and Exhibition. Society of Petroleum Engineers, 2017. http://dx.doi.org/10.2118/185358-ms.

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Chan, Keng Seng, Rahim Masoudi, Abdolrahim Ataei, Nasir B. Darman, and Mohamad Othman. "Reservoir/Well Production Assurance Strategies for Successful Field Development Projects." In SPE Asia Pacific Oil and Gas Conference and Exhibition. Society of Petroleum Engineers, 2011. http://dx.doi.org/10.2118/145879-ms.

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Djanuar, Yanfidra, Qingfeng Huang, Jimmy Thatcher, and Morgan Eldred. "Integrated Field Development Plan for Reliable Production Forecast Using Data Analytics and Artificial Intelligence." In Gas & Oil Technology Showcase and Conference. SPE, 2023. http://dx.doi.org/10.2118/214021-ms.

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Abstract Having a robust field development plan (FDP) for mid-size mature oil fields generally poses considerable challenges in the context of the integrational elements of production forecast, operational environment, projects and surface facilities. An integrated FDP combined with data analytics and artificial intelligence (AI) has been introduced and deployed in a heavily compartmentalized offshore field of Turkmenistan. An integrated approach through data-centric analytics and AI has been proposed for an optimal FDP. It consists of four aspects: model integration, time-series forecast (TSF) of production, AI-assisted operation-schedule generation, and evaluation and selection of scenarios. Firstly, model integration is performed as bringing together both multi-discipline raw data from field measurement and their interpretations that change non-linearly. Secondly, model integration aids in the application of AI for production forecast. A unique AI technique was built to allow raw data and interpretation. Illustratively, the model is capable of forecasting decline curves matching the history production. Meanwhile, engineers’ production forecast inheriting from simulation, machine learning or type curves is also constructed by understanding how/why human-driven forecasts differ from the measured decline and incorporating those insights. In addition, AI-assisted scheduler efficiently allocates resources for operational activities, considering the well planning nature, intrinsic operation properties, project planning process, surface facilities and expenditures. Resources are thus utilized for optimal schedules. Finally, evaluation and selection of FDP scenarios take place by considering the multidimensional matrix of factors. Multiple scenarios are generated and scored, reacting to the change of factors. AI-powered optimization is availed to recommend the most efficient tradeoffs between production and carbon generation. The implementation of the integrated FDP approach has been successfully applied for the generation of production profiles and operation schedules, which reduces the time by 80% and increasing accuracy by 55%. Production forecast for existing wells and future wells proved to be reliable. It achieved the production targets with proper allocation of schedules, by considering multi-discipline constraints. Through AI-assisted scheduler, different types of rigs were properly assigned to the planned wells, which requires additional rigs based on the outcome. The model was agile to the change and sensitivities of wells requirement, projects uncertainties and cost changes. The optimum FDP scenario was recommended for the business decision, operation guide and execution. This approach represents a novel and innovative means of integrating and optimizing FDP considering complex factors using AI methods. It is efficient in merging raw data and interpretations for model integration. It accommodates changes and uncertainties from multiple aspects and efficiently generates optimum FDP in a few days rather than months for giant fields. It is the first robust tool that unites subsurface properties, reservoir engineering, production, drilling, projects, engineering and finance for the corporate FDP.
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Passalacqua, Herminio, Jose Luis Ortiz Volcan, Mohamad Hasan Al Einawi, Jamaneh Mostafa Kadnaji, and Fatemah Karam. "Application of a Multiple Attribute Decision Making Method to Improve Oil and Gas Field Development Projects." In SPE Kuwait Oil & Gas Show and Conference. Society of Petroleum Engineers, 2017. http://dx.doi.org/10.2118/187564-ms.

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Buana, Yosef Setya, Mohammad Aringga Adisatria, and Ahmad Abdul Azizurrofi. "Paper Production Cost Analysis Of Improved Oil Recovery Projects Based On Field Development Plan In Indonesia." In SPE Kuwait Oil & Gas Show and Conference. Society of Petroleum Engineers, 2019. http://dx.doi.org/10.2118/198021-ms.

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Divall, Mark Jonathan. "Methodology of Health Impact Assessments in development projects." In SPE International Conference on Health, Safety, and Environment in Oil and Gas Exploration and Production. Society of Petroleum Engineers, 2008. http://dx.doi.org/10.2118/111734-ms.

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Buset, H., A. Pagenhart, and T. I. Throndsen. "Experience Transfer to Development Projects: How and Who?" In SPE International Conference on Health, Safety, and Environment in Oil and Gas Exploration and Production. Society of Petroleum Engineers, 1998. http://dx.doi.org/10.2118/48830-ms.

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Hansen, B. L. "Hydro’S Supplier Development Project In North-West Russia." In Arctic Shelf Oil & Gas Conference 2004. European Association of Geoscientists & Engineers, 2004. http://dx.doi.org/10.3997/2214-4609-pdb.185.section6_15.

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Feng, Shuqiang. "Upstream Oil and Gas Project Development Timing." In International Oil and Gas Conference and Exhibition in China. Society of Petroleum Engineers, 2010. http://dx.doi.org/10.2118/130008-ms.

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Kozin, Anton, Iskander Mukminov, Ilus Galinurovich Khamitov, Mikhail Alekseyevich Kuznetsov, Vadim Ivanovich Igumnov, and Tofik Azimovich Azimov. "The Unique Experience of Odoptu-more Field Development - a New Stage in Russian Offshore Projects." In SPE Russian Oil and Gas Technical Conference and Exhibition. Society of Petroleum Engineers, 2008. http://dx.doi.org/10.2118/114436-ms.

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Reports on the topic "Oil and gas development projects"

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Richard McMahon and Robert Crandall. Alaska Oil and Gas Exploration, Development, and Permitting Project. Office of Scientific and Technical Information (OSTI), March 2006. http://dx.doi.org/10.2172/896550.

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Richard McMahon, Robert Crandall, Chas Dense, and Sean Weems. ALASKA OIL AND GAS EXPLORATION, DEVELOPMENT, AND PERMITTING PROJECT. Office of Scientific and Technical Information (OSTI), November 2003. http://dx.doi.org/10.2172/822891.

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Richard McMahon, Robert Crandall, Chas Dense, and Sean Weems. ALASKA OIL AND GAS EXPLORATION, DEVELOPMENT, AND PERMITTING PROJECT. Office of Scientific and Technical Information (OSTI), August 2003. http://dx.doi.org/10.2172/823303.

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Angulo Rodríguez, Emilio, and Ariel Yépez-García. The Role of Natural Gas in Energy Transition. Inter-American Development Bank, November 2020. http://dx.doi.org/10.18235/0002868.

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As of 2004 and continuously to this day, the annual growth rate of renewable sources has been greater than that of all fossil fuels combined. In the midst of this transition to cleaner energy, natural gas is the only fossil fuel that has increased its share in the global energy matrix. Technological changes in the LNG supply chain, as well as transformations in the global natural gas market, largely explain this growth. This publication provides evidence on the fundamental role that natural gas plays in the energy transition, given that: (i) its greenhouse gas emissions are substantially lower than those of oil and coal; (ii) it provides the firm power necessary to complement intermittent renewable energies; (iii) it is particularly safe compared to other fossil fuels. In line with these attributes, the International Energy Agency projects that the share of natural gas in the global energy matrix by 2040 will remain stable (around 24%), even in its Sustainable Development Scenario, which would allow to meet the goals established in the Paris Agreement.
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Hatipoglu, Emre, and Zlata Sergeeva. Country Horizon: Russia. King Abdullah Petroleum Studies and Research Center, February 2022. http://dx.doi.org/10.30573/ks--2021-rt02.

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This report provides an up-to-date overview of Russian domestic and foreign policy issues related to the oil and natural gas markets. We also discuss the potential role of hydrogen in Russia’s short-term energy strategy. We present a succinct overview of the domestic determinants of Russian energy policy and then describe Russia’s ongoing and planned energy infrastructure projects. In doing so, we particularly focus on Russia’s recent efforts to bring its new hydrocarbon resources to global markets. We also discuss recent developments related to Russia’s dialogue with its key energy partners.
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Rivard, C. Characterization of shallow aquifers and assessment of potential impacts of oil and gas development activities on these aquifers in the Fox Creek area (AB) - October 2021 update. Natural Resources Canada/CMSS/Information Management, 2021. http://dx.doi.org/10.4095/329088.

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A multidisciplinary and multi-institutional project was initiated in the Fox Creek area (west-central Alberta) in April 2019 to study environmental impacts of hydrocarbon development activities. The initial objective was to specifically study potential impacts on shallow groundwater. However, different Sectors within NRCan later identified the Fox Creek area as a region of interest for developing regional cumulative effects evaluation methods in support of new impact assessment legislation. As a result, the scope is now much broader and the project includes studies of vegetation, forest, snow cover, wetlands, and contributes to a woodland caribou habitat study. The project involves many collaborators from the federal and provincial governments, as well as from the academic community. This project is supported by the GGP and EGP programs.
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Luedeman and Olsen. PR-179-12200-R01 Power Cylinder Timed Lube Oil Injection to Reduce Consumption and Catalyst Fouling. Chantilly, Virginia: Pipeline Research Council International, Inc. (PRCI), April 2013. http://dx.doi.org/10.55274/r0010807.

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This project is driven by concerns over excessive cylinder lubrication in large bore two-stroke natural gas engines (LBNGE). Excessive cylinder lubrication can lead to: - Increased operating costs due to high lubricating oil consumption. - Poisoning of catalytic converters. - Increased pollutant emissions. Development of an electronically-controlled, power-cylinder lubricator (ECPCL) is a likely solution that could decrease excessive cylinder lubrication. This lubricator would optimize cylinder lubrication by controlling both the injection rate and injection timing, relative to piston position.
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Miller. L51659 Diverless Pipeline Repair Clamp I. Chantilly, Virginia: Pipeline Research Council International, Inc. (PRCI), August 1993. http://dx.doi.org/10.55274/r0010264.

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Offshore oil and gas developments are underway for water depths beyond which divers can function. The economic lifelines of these projects are the pipelines which will transport the products to shore. In preparation for the day when one of these pipelines will require repair because of a leak, the Pipeline Research Committee of Pipeline Research Council International, Inc. is funding research directed at developing diverless pipeline repair capabilities. Several types of damage are possible, ranging from latent weld defects on one end of the spectrum to damage resulting in parting of the pipe at the other end. This study is specifically directed toward laying the groundwork for development of a diverless pipeline repair clamp for use in repair of leaks resulting from minor pipedefects. The incentive for a clamp type repair is costs. When compared to replacing a section of pipe, either by welding or by mechanical means, the clamp type repair requires much less disturbance of the pipe, less time, fewer operations and less equipment.
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Miller. L51699 Diverless Pipeline Repair Clamp Phase III. Chantilly, Virginia: Pipeline Research Council International, Inc. (PRCI), August 1993. http://dx.doi.org/10.55274/r0010218.

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Offshore oil and gas developments are underway for water depths beyond which divers can function. The economic lifelines of these projects are the pipelines which will transport the products to shore. In preparation for the day when one of these pipelines will require repair because of a leak, the Pipeline Research Committee of Pipeline Research Council International, Inc. is funding research directed at developing diverless pipeline repair capabilities. This Report summarizes the results of the third and final phase of this project. Phase III work included design, manufacture, and dry testing of 1) a one-half scale model of a 12"� repair clamp, 2) a full-scale bolt test fixture to demonstrate boltcontainment and startup under realistic misalignment of the clamp halves, and 3) a full-scale one-way cylinder for end seal activation. Engineering drawings for a 12" - 900# (324 mm, 15.3 mPa) diverless repair clamp package were also produced, and are provided with this report in Appendix B. Phase III also included a study commissioned from Oceaneering directed at defining the interfaces of the clamp package and the ROV, including suggested procedures for deployment and positioning of the clamp package on the pipeline. Issues regarding bolt make-up by the ROV were also studied in detail and limitations in bolting capability were outlined.
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Cunningham and Wilcox. PR-015-12205-R01 Technology Challenges for Liquid CO2 Pump Stations. Chantilly, Virginia: Pipeline Research Council International, Inc. (PRCI), December 2013. http://dx.doi.org/10.55274/r0010023.

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As a result of proposed new climate change legislation requiring carbon capture and sequestration (CCS) of atmospheric carbon dioxide (CO2) emissions, there has been increased interest in the development of carbon capture technology worldwide. CCS aims to reduce CO2 emissions to the atmosphere by capturing it from the emissions of large producers and storing it underground. One often overlooked component of the CCS process is the transmission of captured CO2 to sequestration sites. This anthropogenic, or man-made, CO2 presents unique challenges to transportation because of the inclusion of impurities such as water (H2O), Hydrogen Sulfide (H2S), Carbon Monoxide (CO), Hydrogen (H2), and Methane (CH4). These impurities cause changes in the properties of the CO2 stream and complicate the design of pipelines. Pure CO2 pipelines for Enhanced Oil Recovery (EOR) have a long history of operation in North America, but this technology must be adapted to anthropogenic CO2 uses. Other technologies can potentially be adapted from the oil and gas industry. There are still challenges to be addressed, however, before anthropogenic CO2 pipeline technology can be considered mature. The objective of this project is to pinpoint areas of CO2 pipeline technology that still require development related to anthropogenic CO2 pump stations and their operation when transporting CO2 as a dense phase or supercritical fluid. This report focuses on identifying these challenges and providing a research roadmap to guide the development of anthropogenic CO2 technology to maturity. This project identified key technology challenges related to the gas properties, equipment, and operation of anthropogenic CO2 pipeline pump stations. Through an extensive literature review, interviews with industry professionals, and input from the PRCI committee, a list of relevant technology challenges was developed. The technologies were then ranked the level of development of these challenges using the Technology Readiness Level (TRL) scale to identify technologies in need of significant development. This report addresses the progress of technologies determined to have a low TRL level of development.
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