Pipeline Owners Research Articles

Owner experience and veterinary involvement with unlicensed GS-441524 treatment of feline infectious peritonitis: a prospective cohort study.

Feline Infectious Peritonitis (FIP) has historically been a fatal coronavirus disease in cats. In recent years, the therapeutic agent GS-441524, developed by Gilead Sciences, was found to be a successful treatment for FIP in most patients in clinical trials. However, this particular drug has remained stalled in the therapeutic pipeline, leaving patients and cat owners without a licensed medication. In the meantime, online social media platforms began to emerge, connecting cat owners with a community of citizen non-veterinary professionals sourcing unlicensed GS-441524. This study prospectively followed participants (N = 141) that successfully completed 12 weeks of treatment, capturing their treatment experiences with self-administered GS-441524-like medication. A one-time survey was administered to enrolled participants with mixed format of questions (open-ended and multiple-choice) asking about treatment administration techniques, observed side effects of GS-441524, accrued cost, veterinarian involvement, impact on the cat-human bond, and social media usage. Our results show cat owners experienced a shift in treatment modality from injectable GS-441524 to pill formulation across the treatment period. The average total cost of medication has decreased since 2021 to approximately USD 3100, and participants reported the human-animal bond being affected negatively. Additionally, there was an increased trend in veterinarian awareness of GS-441524-like therapeutics and monitoring of clients undergoing treatment. Social media usage was reported as being important at the beginning of treatment to establish treatment administration but lessened by the end of treatment. This study is the first detailed, prospective account of owner experiences with unlicensed GS-441524, raising an important discussion surrounding citizen veterinary medicine.

Safety Analysis and Condition Assessment of Corroded Energy Pipelines under Landslide Disasters

Corrosion poses a significant risk to the safety of energy pipelines, while landslide disasters emerge as the primary threat responsible for triggering pipeline failures across mountainous areas. To date, there is limited research focused on the safety of energy pipelines considering the synergistic effect of corrosion and landslides. The present study proposes a finite element (FE)-based model to assess the condition of corroded pipelines under landslides. The effects of corrosion dimensions (length and depth) and location are determined. A novel equation is finally developed to predict the maximum stress and determine the most disadvantageous position for corroded pipelines under various landslide displacements. The results demonstrate that (1) as the landslide progresses, the pipeline’s stress significantly increases; (2) corrosion depth has a more significant impact on the pipeline condition than the corrosion length, and it is positively correlated with the pipe’s stress; (3) the maximum stress exhibits a nonlinear relationship with the landslide-facing position and the corrosion circumferential location; and (4) when the axial position of the corrosion is more than 6.5 m away from the center of the landslide, the location of maximum stress shifts from the corrosion region to the central section of the pipeline within the landslide. This work contributes to helping pipeline owners to understand the applicability of energy pipelines subjected to the combined effects of corrosion and landslides and provides support for future risk assessment efforts in pipeline integrity management.

Introducing best practice for reproducibility in government

There is an appetite to improve the reproducibility of quantitative analysis undertaken across government. Our team supports conversion of regular publications into Reproducible Analytical Pipelines (RAP). To achieve this, we developed a roadmap to work with analysts in our organisation and help them transform their pipelines and build their skills.
 An audit of the current RAP status of all regular pipelines assisted in resource allocation and planning. The maturity of a RAP is evaluated on 7 criteria required to reach a minimum viable product (MVP) and 7 additional advanced criteria as outlined by the Analysis Function (AF). We use a combination of hands-on pair-coding with analysis teams, regular and ad hoc code reviews, and training sessions to convert existing pipelines into RAPs, while simultaneously upskilling the analysts. We have also developed guidance and training documentation to share internally and externally.
 Currently, out of 73 regular publications, 12 have reached the MVP, with an average score of 4.36 out of 7. This scoring is reassessed monthly, allowing us to track the progress in real-time. Self-assessment of technical skills increased by between 43% and 89% and 97% said their understanding of RAP principals improved because of the training and 77% said they are now able to implement best practice into their work. By working with the pipeline owners instead of just refactoring the code directly, we are ensuring business resilience. The in-depth knowledge of the pipeline and skills required to maintain it are present within the analysis team. Publishing our methods, documentation and tools facilitates adoption of RAP for those without a dedicated RAP team.
 We are on track to convert all our regular publications into RAPs and move to “RAP by default”, in line with the AF RAP Strategy. This will improve the reproducibility, quality, efficiency, transparency, and trustworthiness of analysis within government. We hope other organisations can learn from our methods.

Правовые аспекты обеспечения прав титульного владельца газопровода при выполнении работ на чужих земельных участках

This article is dedicated to a complex study of the issues of protection of rights of title gas pipeline holders (gas pipeline owners and gas pipeline operating companies) in performance of engineering works on gas transmission network sections located within the boundaries of land plots owned by others. Considering the special nature of a gas transmission network as a source of increased danger and a hazardous industrial facility, the author believes that one of the priority areas of gas pipeline operation is regular diagnostics and maintenance as well as in-process current (emergency) repair performed to avoid any breakdowns of the normal operation mode of the gas transmission network and causing of damage to lives, health and property of third parties. Taking into account these circumstances and the specifics of legal regulation of gas pipeline operation, the author of the article singles out the legal problem that lies in the ambiguity of approaches to the solution of the issue of provision of the title gas pipeline holder with access to the operated section of the gas transmission network if such facility is located within the boundaries of a land plot not owned by the gas pipeline holder. In order to solve this problem, the author performs a systemic analysis of the applicable laws of the Russian Federation and the legislative practice of some foreign countries and singles out three key concepts of provision of access to a gas pipeline located at a land plot owned by another person; such concepts include an opportunity to establish private or public easement and imperative proclamation of the unconditional right of the gas pipeline holder to unrestricted access to any section of the operated gas transmission network irrespective of the ownership of land plots such sites are located at. The author gives a systemic evaluation of each of the mentioned conceptual approaches; based on such evaluation, the author brings forward recommendations for improvement of the applicable laws to comply with the proclaimed principle of ensuring energy security of the Russian Federation.

Pipeline sharing: Potential capacity analysis of biofuel transportation through existing pipelines

In response to resource depletion and tightening carbon emissions policies, the product oil is gradually being substituted by biofuels and faced with falling demand. A large number of studies have been done on the optimization of the biofuel supply chain, but few of them have considered the existing petroleum pipelines for policy reasons. Market-based reforms in the oil and gas industry have provided the possibility of pipeline sharing, whereby pipeline owners can use the remaining delivery capacity to transport other liquid fuels that are allowed into the pipeline, such as biofuels, thereby increasing pipeline benefits and reducing biofuel logistics costs. This paper develops a logistics optimization model considering multi-product pipeline scheduling from the perspective of biofuel suppliers and proposes a pipe-rail transportation mode to assess the optimization potential of logistics costs. Finally, this paper verifies the feasibility of the proposed approach using a logistics system in a region of China as a practical case study and conducts a sensitivity analysis on whether changes in the demand for product oil and biofuels affect the choice of pipeline opening location, concluding that there is no effect within a 4-fold increase in biofuel production and a 0.78-fold decrease in product oil demand.

Exploring Networked Project Coordination in Combined Utility Streetworks

Combined utility streetworks involve cable and pipeline owners and authorities that concurrently undertake work in the same physical space. In this networked project setting, ownership fragmentation and lacking formal coordination instruments complicate the integration of multi-stakeholder engineering and construction operations. Boundary spanners have a unique position to pursue integration in this complex system. To understand what it is that constitutes their practices, we explore them through Mintzberg’s seminal framework of informational, interpersonal, and decisional roles. Specifically, we extend the framework to the context of boundary spanning in networked projects by conducting semi-structured interviews with seven boundary spanners of combined utility streetworks: the so-called utility coordinators. Based on open coding of the interview data, we identified 149 performed activities, and twenty-three lower-level management roles (such as involving stakeholders; facilitating formal processes; and, creating a collective memory). Next, axial coding allowed us to tailor Mintzberg’s role model to networked project settings. Based on this, we reflect on how a setting that lacks formal coordination instruments influences the roles that boundary spanners adopt. This empirical study of coordination in networked projects contributes a case to the practice turn literature that calls for explorations of everyday organizational practices in their situated context. Other contributions are the extension of Mintzberg’s framework to networked projects; and, the development of two hypotheses about the position and roles of utility coordinators. Eventually, our findings may help practitioners identify what interpersonal and informational skills they need to improve alignment in loosely connected project networks.

Steep Creek Risk Assessment for Pipeline Design : A Case Study From British Columbia, Canada

ABSTRACT Pipelines in mountainous terrain often cross alluvial fans formed by steep creek processes of debris flows and debris floods and are thus exposed to their associated hazards. The design of new pipeline infrastructure and maintenance of existing pipelines necessitates steep creek risk assessments and appropriate mitigation design. We present methodology for assessing steep creek risk along pipeline routes that evaluates the probability of such processes causing a pipeline loss of containment or disruption in service. The methodology consists of estimating event frequency, scour potential, and the vulnerability of the pipeline to break if impacted by boulders. The approach can be adapted to other landslide geohazards so that different geohazard locations can be evaluated with a common metric. Steep creek process frequency is estimated based on field observations and review of documented events, historical air photo records, and terrain mapping based on LiDAR-generated topography. Scour potential is estimated based on channel morphology, presence of bedrock, and grain size distribution of channel bed material. Vulnerability is estimated based on flow width and velocity and can be modified for different pipe diameters and wall thicknesses. Mitigation options for buried pipelines include those intended to decrease the likelihood of the pipeline being exposed and to increase the resiliency of the pipeline to boulder or organic debris impacts, if exposed. The methodology presented is embedded in risk-informed decision making where pipeline owners and regulators can define probability thresholds to pipeline exposure or rupture, and pipeline designers can demonstrate that proposed mitigation measures achieve these threshold criteria.

Making upstream infrastructure collaboration happen

Major upstream and midstream developments are required in Australia to sustainably address the east coast gas price challenge and enable a new wave of liquefied natural gas (LNG) projects in Western Australia (WA) and the Northern Territory. Until now, each project in the WA offshore and Queensland coal seam gas systems has had its own midstream infrastructure, which is suboptimal for costs. Major players, including Chevron and Woodside, have expressed interest in a more optimal, shared ownership model, similar to others around the world. In the US Gulf of Mexico, pipeline owners established master limited partnerships to take advantage of tax benefits and to share cost with institutional investors. In Norway, high infrastructure costs led to government-mandated shared ownership. The momentum for change in Australia is gathering and includes increasing investor pressure on capital discipline for upstream companies, strong competition for final investment decisions across global LNG projects, stakeholder expectations to minimise the environmental footprint of energy projects, a strong appetite of infrastructure and pension funds for energy infrastructure assets and pipeline companies looking to expand their portfolios to realise synergies in view of increasing regulatory scrutiny and margin restrictions. This paper describes international benchmarks, identifies blockers and proposes action steps that will enable this crucial industry development.

Comprehensive method of natural gas pipeline efficiency evaluation based on energy and big data analysis

Pipeline companies deploy a series of pipeline resource optimal configurations and efficiency enhancement strategies with the purpose of improving financial benefits. Thus far, pipeline owners and stakeholders have usually focused on efficiency evaluation processes based on the technological aspects of transmission. In this context, here we derive a pipeline efficiency evaluation method from the perspective of the pipeline energy input–output by monitoring the energy and transmission amount changes along the pipeline. The parameter of volumetric work, which is defined as the energy consumption required for transporting a certain amount of gas over a certain distance along the pipeline, measures the energy change except for the intrinsic energy and mechanical pressure energy. With no distribution stations being taken into consideration, the gas amount change due to the pipeline's self-energy consumption is regarded as the equivalent fuel gas while also considering the volumetric work change caused by gas consumption. Upon accounting for all factors via volumetric work and pressure energy, we utilise the input–output variation to develop a data envelopment analysis (DEA) model, which affords the relative efficiency via calculation and evaluation of the operating efficiency of the pipeline and related facilities. Subsequently, analytic hierarchy process (AHP) is introduced to determine the impact from different facilities. Our result, which presents the difference between the ideal objective efficiency and current efficiency based on the measured volumetric work can aid in identifying the most efficient situation. Here, we note that owing to factors such as the inlet pressure and equipment configuration, the first station usually exhibits lower efficiency than the other stations. In terms of energy for the whole pipeline, the efficiency (unit consumption) grows in inverse proportion to the transmission amount. In the final phase of the study, we consider an actual pipeline case study in our analysis and verify the practical utility of this method. Our results also indicate that the transmission efficiency and economic efficiency exhibit a trade-off relationship.

Novel Films Based on Inexpensive and Readily Available Materials for Use As a Hydrocarbon Sensor

One of the most commonly cited arguments against erecting and using pipelines to transport oil and gas, is that of the potential leaking of these compounds into the environment. These leaks can infiltrate water systems, kill wildlife and contaminate soil. In many instances, pipeline owners are unaware of leaks. In Alberta (Canada), it was found that, on average, it can take as long as 48 days to respond to and isolate a pipeline leak (according to the Alberta Energy Regulator)1. In Canada alone, there are an estimated 825,000 kilometers of pipeline infrastructure already in operation2. The depth of cover for pipelines varies, depending on where the pipeline is located, creating significant challenges when monitoring pipelines for leaks. Identifying gas seepages is significantly easier than liquid leaks, as gases rise up out of the ground. Liquids, on the other hand, seep down into the ground, compounding the issue. In this work, a novel fabrication process for a single use, low-cost liquid hydrocarbon sensor has been developed. The process is simple, and the materials are readily available and low cost. The film has controllable hydrophilicity and can present amphiphilic properties, as well as strong electrical conductivity. We have successfully applied this film as a sensor for the presence of hydrocarbons that could be found in the event of a leak from an oil pipeline. The sensor responds rapidly to alkanes of varying lengths and has also shown strong responses to both functionalized hydrocarbons and aromatics. The sensor is both inexpensive and easy to manufacture, with scale-up being a matter of simply using a larger container for the synthesis. The sensor does not respond to water, a potential interferent for a sensor placed in soil, and has shown good stability towards dessication and long-term storage. Combined, this supports the application of such a device for the field detection of organic compounds commonly found in the presence of an oil spill or pipeline leak.

Natural Gas Liquids—Regulation: FERC/Not FERC? Determining Jurisdictional Status of NGL Pipeline Service

AbstractAs the production of natural gas liquids (NGLs) has increased during the last five years—rising almost 40 percent from 2006 to 2012—existing pipeline transportation infrastructure has proven inadequate to handle these increased volumes of NGLs. The industry has responded to the need for NGL infrastructure investment in a variety of ways: by expanding existing NGL pipelines, repurposing pipelines that currently are idled or being used to transport other commodities, reversing existing lines, and constructing new greenfield pipelines. As the investment required for these NGL pipeline projects is significant and the demand for NGL transportation service is high, understanding the jurisdictional status of NGL pipeline transportation service and the regulatory implications of that status is imperative to pipeline owners and NGL producers alike. This article provides an overview of the jurisdictional question and examines the factors that are used to determine whether a NGL pipeline's transportation service will be subject to federal jurisdiction.

Modeling Deterioration in Concrete Pipes as a Stochastic Gamma Process for Time-Dependent Reliability Analysis

Concrete sewer pipes encounter corrosion as a predominant form of deterioration that reduces the service life of the pipeline system and increases the costs of maintenance and rehabilitation. Reliability analysis can help pipeline owners and sewer-system managers to predict the service life of the pipes and the time for repair or replacement. To include uncertainties in the reliability analysis, the corrosion process can be considered a stochastic process. This paper presents a stochastic gamma process model to account for temporal variability and uncertainties associated with the corrosion process in concrete sewer pipes that typically increase the probability of failure with the aging of the pipe. The proposed methodology is then applied to a specific concrete sewer system. The key element of the proposed method is the use of the gamma process concept. A gamma process can model the monotonic behavior of the ageing and deteriorating process. The application of the gamma process presented in this paper can potentially contribute to widening the use of stochastic processes for the modeling of structural degradation processes such as wear, fatigue, corrosion, crack, erosion, and creep.

CHANGES TO GAS ACCESS LEGISLATION—POLICY RATIONALE AND IMPLICATIONS FOR INDUSTRY

The introduction of a national gas access regime has coincided with a rapid expansion in the Australian market for gas transportation services. The threat of regulation and the approach of regulators, however, have influenced both the configuration of pipelines and the nature of transportation contracts. The recent introduction of reforms to the National Third Party Access Regime for Natural Gas Pipelines (Gas Access Regime), and to part IIIA of the Trade Practices Act 1974 (Cth), has the effect of introducing part but not all of the reforms recommended by the Council of Australian Governments’ Independent Review of Energy Market Directions, and the Productivity Commission’s Review of the Gas Access Regime. The principal amendments, relating to the insertion of an objects clause and the introduction of regulatory holidays for certain greenfield projects are also likely to influence the configuration of pipelines and the nature of pipeline contracts. These amendments are precursors to a major restatement of National Gas Access legislation that will, if enacted, have the effect of creating greater uniformity between the National Electricity Law and the regulatory environment that will apply to gas, but, will also open up the opportunity for pipeline owners and operators to submit to a lighter form of regulation.

CAPM and Risk in the Australian Regulatory Context

As one component in the determination of price caps for access to regulated gas pipelines under the National Access Code for Natural Gas Pipeline Systems (which is given legal effect through relevant State legislation), regulators utilise the CAPM to determine a 'reasonable' rate of return on the capital employed by the pipeline owner in the provision of gas transport services. A key issue in the use of CAPM in this manner is the determination of beta, the coefficient measuring systematic risk in the CAPM. Pipelines are not commonly traded in Australia, and hence market betas cannot be readily calculated from market data. This necessitates estimation of beta by other means. The methods used in practice is essentially a combination of comparisons with like pipelines which are traded (usually in the US or UK) combined with what can best be described as guesswork to incorporate differences between these pipelines and the pipelines being regulated. This process is less than rigorous and subject to rent-seeking behaviour by pipeline owners. This paper considers risk from the perspective of first principles, and derives a methodology for determining beta in the Australian regulatory context based upon a theoretical consideration of diversification choices of individuals.

High-speed electric drives: technology and opportunity

This article provides background on the development and installation of high-speed electric motors (induction and synchronous) and controllers. There are compelling reasons for electric drives to be considered for applications that would conventionally be driven by steam turbines, gas turbines, and engines or motors with speed-increasing gearboxes. Electric drives offer an opportunity for efficient use of natural resources, clean and (comparatively) quiet power conversion, improved process control, and very attractive life-cycle cost. High-speed electric drives utilize technology (including variable speed control) to meet the needs of a rapidly changing industrial world. The high-speed electric drive provides another valuable option for consideration by the gas pipeline owner. This option needs to be considered as part of initial strategic planning. The electric option offers many system benefits for pipeline owners. It represents proven technology, and significant potential opportunity.

THE NATIONAL THIRD PARTY ACCESS CODE FOR NATURAL GAS PIPELINE SYSTEMS

The National Third Party Access Code for Natural Gas Pipeline Systems is a result of February 1994 recommendations made by the Council of Australian Governments. The Code establishes a third party access regime which, when implemented, will apply to gas transmission pipelines and gas distribution systems.This paper provides an overview of the Third Party Access Code. It examines the scope of the Code; the procedure by which the Code is made to apply to new pipelines; the content of access arrangements required under the Code; and the provisions for third party access and dispute resolution. The paper also notes various miscellaneous provisions in the Access Code which address issues such as ring-fencing of pipeline services and the prohibitions on hindering access.The paper concludes with some practical guidance on steps the gas industry can take in response to the Access Code. These steps are suggested from the perspective of existing and prospective pipeline operators and owners, as well as from the perspective of pipeline users and prospective pipeline users.

THE COOPERATIVE DEVELOPMENT OF THE GOBE OIL FIELDS

The proposed Gobe Petroleum Development Project includes the development of two separate oil fields, SE Gobe and Gobe Main. The fields are located, respectively, in the northwestern area of Petroleum Prospecting License (PPL) 56 and the southeastern area of PPL 161 in the Gulf and Southern Highlands provinces of Papua New Guinea, approximately 500 km northwest of Port Moresby, 80 km northwest of the town of Kikori and 85 km southeast of the Kutubu oil fields.The Gobe anticline, on which the discovery wells were drilled, is a large east-southeast trending ridge situated at the leading edge of the Papuan Fold Belt. The surface of the anticline was formed by folded limestone which has weathered to produce a rugged terrain characterised by intense pinnacle karst topography. Dense rainforest covers all of the project area. The crest of the anticline is in excess of 1,300 m above sea level, with the hydrocarbons occurring between approximately 900 m and 1,200 m below sea level.The Gobe Main Field is located entirely within PPL 161 which is operated by Chevron Niugini Pty. Ltd. The SE Gobe Field is located within both PPL 56 and PPL 161. The PPL 56 license is operated by Barracuda Pty Limited. Both of the fields are situated approximately 15 km from the existing Kutubu oil export pipeline. Development planning for the two fields is now at a mature phase and the two license groups are preparing to submit Petroleum Development License Applications (PDLA) to the PNG Government. Initial production is targeted for December of 1997 and the fields are forecast to produce at a combined peak rate of approximately 50,000 BOPD.The potential economic return to participants and the state will be optimised by developing these fields in a cooperative manner with shared production facilities. Similarly, utilisation of the nearby Kutubu oil export pipeline will yield benefits to both the field developers and pipeline owners. The Gobe development serves as an example of how the economics of two 'marginal' field developments can be enhanced by employing existing infrastructure and sharing of facilities. This paper will provide an overview of this cooperative approach to development.

Designing ‘smart’ computer-assisted markets: An experimental auction for gas networks

We study a sealed bid-offer auction market for simultaneously pricing natural gas at each delivery outlet, source, and on all pipelines that connect sources with delivery points. Wholesale buyers submit location-specific bid schedules for amounts of delivered gas at corresponding prices. Wellhead owners submit location-specific offer schedules for amounts of produced gas they are willing to sell at corresponding offer prices. Pipeline owners submit leg-specific schedules of transportation capacity they are willing to commit at corresponding prices. A computer algorithm maximizes total gains from exchange based on the submitted bids and offers and determines allocations and non-discriminatory prices at all nodes.

ASSESSING THE COMPETITION FACED BY OIL PIPELINES

This paper assesses the competition faced by oil pipelines. It also uses a new procedure and new data to test whether oil pipeline markets are competitive or monopolistic, under standard definitions. The key innovation of the paper is a new approach to the definition of the relevant market(s) in which oil pipelines operate. While recognizing that pipeline monopsony also could be a problem under certain conditions, the paper argues that these conditions are unlikely to arise and that if they do, it is unclear whether pipeline owners would be in a position to exploit them. The study offers new evidence to fuel the 80‐year‐old debate over pipeline rates and regulation.

PIPELINES AND PIPEDREAMS

There is little Australian experience to work on but the available evidence indicates that the capital cost of installing pipelines in Australia is well in excess of the cost of building similar size lines in the United States. The terrain in which the line is being laid is an important factor in total cost.The costs of operating a gas pipeline are essentially determined by the cost of installation of the line and the cost of the funds used. The first of these factors is largely outside the control of the operator although it does have some discretion in areas such as the source of the pipe to be used. The cost of the funds used in a project is dependent on the status of the owner and while private pipeline owners have tended to be low cost borrowers, government bodies should be able to obtain better rates of interest. However, the source of government funds is limited and the allocation of these funds should be determined by suitable tests of social and economic benefits.Given the capital and financial costs of a pipeline the unit cost of transporting gas is a direct function of throughput and the variation in that throughput.Even under generous usage assumptions, the pipe which is projected to join the North West Shelf to the East Coast will not be economic for many years. Provision of funds from consolidated revenue and other devices will not reduce the costs but merely divert them to taxpayers. Pipelines to some of the more remote areas will probably never be economic.