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Results
Damping Identification From Subsea Logger Axial Riser Response Data
Lim, HyeongUk (Stress Engineering Services, Inc.) | McNeill, Scot (Stress Engineering Services, Inc.) | Kluk, Daniel (Stress Engineering Services, Inc. (Corresponding author)) | Stahl, Matthew (Stress Engineering Services, Inc.) | Puskarskij, Konstantin (Copenhagen Energy Partners) | Hansen, Kristian (Maersk Drilling)
Summary For decades, it has been known that, as drilling riser deployment depths increase, the potential for excessive hookload response will also increase. Using data collected from a drilling riser deployed to a record-setting water depth, nearly 12,000 ft, this paper provides insight that significantly reduces uncertainty about the severity of this resonant response. The typical drilling riser and blowout preventer (BOP) stack, disconnected from the wellhead, has its first axial resonant period at approximately 1 second for every 2,000 ft of deployed length, thus 5 seconds for 10,000 ft, 6 seconds for 12,000 ft, and so on. Therefore, vessel heave response can incite a significant, adverse axial resonant condition in very deep water. Damping reduces resonant response. Historically, the true amount of damping has been uncertain, and damping has been applied in the form of hydrodynamic drag. This typically produces a predicted response with total damping that is well under 1% of critical. This can lead to the prediction of a large dynamic hookload that can produce significant restrictions on riser configuration (running weight) and seastate for BOP stack deployment as well as storm hang-off of the riser and lower marine riser package (LMRP). A recent drilling riser deployment to the record-setting water depth of 11,903 ft produced a unique opportunity to collect high-quality data that reduces damping uncertainty. This paper describes damping ratio and natural frequency identification for the first few axial riser modes for this deployment. The data were collected during deployment and retrieval using subsea vibration data loggers (SVDLs) installed on the BOP stack, drillship, and riser. These measurements reveal damping that is between 2% and 3% of critical. This result can be used to provide more accurate predictions of dynamic hookload response.
- North America > United States (0.30)
- North America > Canada (0.28)
- Europe > Norway (0.28)
Abstract Large-scale CO2 and energy storage is a mandatory part of the green shift to reduce CO2 emissions and limit consequences of climate change. Large-scale storage will require the use of shut-down depleted hydrocarbon fields to take advantage of well-characterized reservoirs and cap rocks. Thanks to extensive data from historical hydrocarbon production, the uncertainties related to storage capacity, injectivity, and containment are limited. However, legacy exploration and production infrastructure, and especially legacy wells, are the main threat for possible fluid leakage toward the surface. Such legacy wells are numerous and penetrate the full rock column. In this paper, we describe a workflow to screen and monitor legacy wells in the shut-down Frigg Field in the North Sea. By using numerical modeling of electromagnetic (EM) field propagation in one of the Frigg Field wells, we explore the complex interactions of fields, currents, and well structure in the presence of corrosion. The corrosion is implemented as a change in the electrical conductivity of the innermost steel casing at different depths along the structure. To enhance probing depth, we plug the dipole source (1 km long) into the casing at the seafloor and excite the casing as an antenna. We find that at moderate levels of corrosion, the current distribution is significantly modified with respect to the uncorroded case. This generates a signal that propagates and can be observed at the seafloor in the numerical results. Other elements of the well geometry (e.g., concentric overlapping cement casings) have their own effect on the signal. This leads the possibility of estimating the location of the corroded area within the well geometry. These results suggest that by relaxing some of the model's approximations and implementing realistic transmitters, it will be possible to evaluate and optimize controlled-source EM survey strategies for detecting and monitoring corrosion levels.
- Europe > Norway > North Sea (0.92)
- Europe > United Kingdom > North Sea (0.92)
- Africa > South Africa > Western Cape Province > Indian Ocean (0.24)
- North America > United States > Texas > Dawson County (0.24)
- Oceania > Australia > Victoria > Otway Basin > Naylor Field (0.99)
- Europe > United Kingdom > North Sea > Northern North Sea > South Viking Graben > Block 10/1 > NOAKA Project > Frigg Field > Frigg Formation (0.99)
- Europe > United Kingdom > North Sea > Northern North Sea > Viking Graben > PL 030 > Frigg Formation (0.97)
- (3 more...)
ABSTRACT Since some years back a new class of Oilfield corrosion inhibitors have been available on the market, oligomeric film-forming inhibitors. In contrast to the standard cationic surfactant type, these chemistries contain multiple positively charged hydrophilic headgroups. These amine-based inhibitors have proven to be broadly applicable, and compatibility studies have shown some of these active bases to be extremely flexible in formulation, allowing a wide range of corrosion inhibition solutions. Further, some of these novel products also fulfill North Sea environmental criteria for offshore application allowing use globally in environmentally restricted areas. The purpose of this paper is to outline and summarize the performance of this inhibitor class under different conditions and how these materials are meeting the diverse challenges connected to use in the oilfield area. This includes e.g. sweet and sour corrosion, severe brines and various compatibility issues. INTRODUCTION Background The standard type of chemicals long used as oilfield corrosion inhibitors are so-called film-forming molecules carrying a positive net charge. More specifically, these additives belong to e.g. the classes fatty amines, alkoxylated fatty amines, amidoamines, imidazolines, pyridinium quats, and quarternary ammonium compounds like alkyl benzyl quats. Anionic molecules, predominantly phosphate esters, may sometimes also be used as stand-alone inhibitors or as enhancers in formulations with a base inhibitor of the abovementioned type. A common feature of these chemicals is that they are surface-active. This property is inherently required by the application where key elements include the correct distribution between oil- and water phases and a good attachment to metal surfaces, enabling the creation of a water-repelling film. A second characteristic is that they are monomeric, and normally contain one, or (rarely) two hydrophilic headgroups and similarly one or two hydrophobic alkyl chains. However, over the past few years a new type of corrosion inhibitor chemistry has appeared on the market. The differentiating feature of these novel molecules compared to the traditional type is that they contain multiple hydrophilic (positively charged) headgroups, and in some cases, also multiple hydrophobic alkyl chains. An obvious advantage of this structure is that it enables several potential points of adhesion to the metal surface. Since these structures have a higher molecular weight than the common types, and frequently consist of a few repetitive structure elements, but still cannot be correctly classified as "polymeric", they will be referred to as "oligomeric" in this paper. These oligomeric inhibitors also, in line with the "standard monomeric type", carry surface active properties. The aim of this paper is to summarize experiments with this novel chemistry to meet the diverse corrosion inhibition challenges connected to the use in oilfield applications area including e.g. sweet and sour corrosion, difficult brines and diverse compatibility issues.
- Europe (1.00)
- Asia > Middle East (0.68)
- North America > United States > Texas (0.46)
- Materials > Chemicals > Commodity Chemicals > Petrochemicals (1.00)
- Energy > Oil & Gas > Upstream (1.00)
- Well Completion > Well Integrity > Subsurface corrosion (tubing, casing, completion equipment, conductor) (1.00)
- Production and Well Operations > Production Chemistry, Metallurgy and Biology > Corrosion inhibition and management (including H2S and CO2) (1.00)
- Facilities Design, Construction and Operation > Pipelines, Flowlines and Risers > Materials and corrosion (1.00)
ABSTRACT The paper is designed to outline the benefits of using an online continuous corrosion monitoring system to drive revenue through process optimisation. Emerson's Plantweb Insight applications for corrosion excellently compliment operators needs to address current industry challenges, such as tighter CAPEX budgets, reduced experienced operators, and the ever-changing demands of the modern process industry. The software is henceforth referred to as "plant software". The corrosion applications for this software platform are designed for continuous analysis and corrosion monitoring trends for installed wireless corrosion sensors. The application delivers insight to instrument health and includes advanced analytics to determine metal loss rates and corrosivity. Reliable corrosion data is critical to understanding the impact of ever-changing conditions in the plant. Operators integrating reliable corrosion data into their process historians can optimize their assets, expertly navigating the tightrope to increased revenue and operational certainty. Operators can see both corrosion risk and corrosion impact on plant health, through an easy to use visualisation and analytics platform. Lower grade feedstocks and faster flowrates can be utilised with increased visibility of the health of the assets. Crude oils that are not typically used as feedstocks due to their high sulfur content, acidity, or other impurities, also known as opportunity crudes, can increase revenue by millions of dollars per year for an average sized refinery. With the corrosion applications delivering regular data to desk, operators no longer work blindly, relying instead on accurate high-quality data to make informed decisions. INTRODUCTION Over the past decades cost pressure in oil refining has increased, especially in Europe where the consumption of oil products is decreasing over time. Refineries are investigating ways to increase margin and, given that they account for around 80% of total refinery expenditure, reduction of crude oil cost is a key factor. One way of doing this is to purchase cheaper and generally less desirable crude from global markets. These crudes often have elevated sulphur content or acidity. These crudes are less desirable due to the increased risk of corrosion through fouling and coking.
- Europe (0.88)
- Asia > Middle East (0.47)
- North America > United States > Texas (0.28)
- Well Completion > Well Integrity > Subsurface corrosion (tubing, casing, completion equipment, conductor) (1.00)
- Production and Well Operations (1.00)
- Facilities Design, Construction and Operation > Pipelines, Flowlines and Risers > Materials and corrosion (1.00)
ABSTRACT This paper will detail the thirty year history of the use of linear anode anodes to protect older generation pipelines with aging coatings. The presentation will discuss the original polymeric linear anode and the product's history of evolution to today's MMO coated titanium wire anode. The paper will then discuss aging pipelines and the problem that creates for the effective application of cathodic protection. The paper will briefly discuss recoating as an option before diving into the application of linear anodes including installation methodologies and design considerations. The paper will then present some case stories and examples of successful installations. INTRODUCTION There is a long and successful history of using linear anodes to cathodically protect older generation pipelines with aging coatings. The use of linear anodes to address poor cathodic protection distribution has proven to be easier and more cost effective than large scale recoating projects. While the use of linear anodes is common in the United States, there are many similar vintage pipelines in Europe, the Middle East and Asia which struggle with the same challenges and for whom this technology should be of great interest. A BRIEF HISTORY OF LINEAR ANODES The first linear anode product appeared in the mid to late 1990s. It was a revolutionary anode concept โ a flexible long length anode cable intended to operate at low current outputs. This first generation linear anode included several key features that remain the standard for today's linear anodes: packaged sock diameter, fabric housing, and braiding to protect the fabric housing and help ensure even coke compaction. There were also some unique flaws in the first generation linear anode. The anode material itself was a conductive polymer formulation that doubled as the insulation on the anode lead wire. This dual role of anode and cable insulation was a major flaw. Notably, the use of a polymeric anode while extremely creative, was a very poor choice of anode material. The polymeric anode is subject to cracking at any area of localized high current output. Since the anode also doubled as cable insulation, when the anode cracked, the conductor was exposed and quickly went into solution yielding to an open circuit anode failure.
- North America > United States (0.34)
- Europe > Middle East (0.24)
- Asia > Middle East (0.24)
- Africa > Middle East (0.24)
- Production and Well Operations > Production Chemistry, Metallurgy and Biology > Corrosion inhibition and management (including H2S and CO2) (1.00)
- Facilities Design, Construction and Operation > Pipelines, Flowlines and Risers > Materials and corrosion (1.00)
- Well Completion > Well Integrity > Subsurface corrosion (tubing, casing, completion equipment, conductor) (0.95)
Corrosion Inhibition of Benzyl Quinoline Chloride Derivative-Based Formulation for Acidizing Process
Yang, Zhen (Key Laboratory of Unconventional Oil & Gas Development, China University of Petroleum (East China)) | Wang, Yefei (Shandong Key Laboratory of Oilfield Chemistry, School of Petroleum Engineering, China University of Petroleum (East China)) | Yang, Jiang (Key Laboratory of Unconventional Oil & Gas Development, China University of Petroleum (East China)) | Wang, Jing (Shandong Key Laboratory of Oilfield Chemistry, School of Petroleum Engineering, China University of Petroleum (East China) (Corresponding author)) | Finลกgar, Matjaลพ (Key Laboratory of Unconventional Oil & Gas Development, China University of Petroleum (East China))
Summary Due to the severe and rapid corrosion of metallic equipment by strong acids at high temperatures, a high concentration of acidizing corrosion inhibitors (ACIs) is required during acidizing processes. There is always a need to develop more effective and environmentally friendly ACIs than current products. In this work, a highly effective ACI obtained from a novel main component and its synergistic effect with paraformaldehyde (PFA) and potassium iodide (KI) is presented. The ACI was prepared from the crude product of benzyl quinolinium chloride derivative (BQD) synthesized from benzyl chloride and quinoline in a simple way. The new ACI formulation, named โsynergistic indolizine derivative mixtureโ (SIDM), which consists of BQD, PFA, and KI, showed superior corrosion inhibition effectiveness (IE) and temperature stability compared with commercially available ACI. More importantly, the SIDM formulation eliminates the need for commonly used highly toxic synergists (e.g., propargyl alcohol and As2O3). In a 20 wt% hydrochloric acid (HCl) solution, the addition of 0.5 wt% SIDM mitigates the corrosion rate of N80 steel down to less than 0.00564 lbmยทft at 194ยฐF, while the corrosion rate at 320 ยฐF is 0.0546 lbmยทftยทwhen 4.0 wt% SIDM is added.
- Europe (0.68)
- North America > United States > Texas (0.47)
- Energy > Oil & Gas > Upstream (1.00)
- Materials > Chemicals > Commodity Chemicals > Petrochemicals (0.69)
- Well Completion > Well Integrity > Subsurface corrosion (tubing, casing, completion equipment, conductor) (1.00)
- Well Completion > Acidizing (1.00)
- Production and Well Operations > Production Chemistry, Metallurgy and Biology > Corrosion inhibition and management (including H2S and CO2) (1.00)
- Facilities Design, Construction and Operation > Pipelines, Flowlines and Risers > Materials and corrosion (1.00)
Abstract A study entitled "Long Subsea Tie-back Solutions for Pre-salt fields" was launched to compare different architectures concerning the hydrate and wax risks. In general, it aims the development of technical solutions and technologies applied to long subsea tie-back on pre-salt fields as a technically feasible and profitable solution. A fictive pre-salt field of two production wells located at 2,500m water depth tied back to a FPSO with a production flowline of around 30 km is considered. This study started with a screening study to assess the technical feasibility of different "single line" concepts. A cost estimate study has been done in parallel to support the most cost-effective solution. Five architectures have been investigated: Two architectures without subsea processing: 1 trunkline; 2 single lines. Two architectures with Subsea Separation Unit (SSU): SSU close to wells. SSU at riser base. One architecture with Multi Phase Pump (MPP) MPP close to wells. At the end of this phase, only three architectures Trunkline, Riser Base SSU and MPP architectures have been retained as the most attractive ones in terms of operability and costs (as indicated in the Fig 1). The concept Subsea Separation Unit (SSU) located close to wells even if inducing low costs was not kept as difficult to operate within the production field life. The two single lines concept was not competitive compared to the trunkline one. Moreover, in terms of costs, a strong incentive has been demonstrated for "lighter" architecture concepts (i.e. a flowline thermal insulation of a wet insulated flowline compared to a Pipe in Pipe (PIP) flowline and without flowline heating system such as electrical trace heating with pipe in pipe insulation (ETH-PIP) technology).
- North America > United States > Louisiana (0.66)
- South America > Brazil (0.47)
- Europe > France (0.29)
- Reservoir Description and Dynamics > Reservoir Characterization > Exploration, development, structural geology (1.00)
- Facilities Design, Construction and Operation > Pipelines, Flowlines and Risers > Piping design and simulation (1.00)
- Production and Well Operations > Production Chemistry, Metallurgy and Biology > Inhibition and remediation of hydrates, scale, paraffin / wax and asphaltene (0.99)
Abstract The European Commission's Climate Target Plan aims to reduce greenhouse gas emissions to net zero by 2050. Hydrogen is considered an important element in achieving these targets, and a hydrogen-based economy requires safe and cost-effective transportation and storage methods. One option gaining consideration is pressurized gas transportation and storage, which takes advantage of existing pipeline infrastructure. To this end, the European Hydrogen Backbone initiative has been launched, with 31 energy infrastructure operators working to develop a dedicated hydrogen network, primarily through the repurposing of existing pipelines. One of the main challenges in this initiative is ensuring the material suitability of pipelines for hydrogen service, given the unique properties of hydrogen that can affect the material properties of steel pipelines. This paper presents RINA experience gained during an independent verification of the material suitability to hydrogen service of the pipeline network operated by the main Italian TSO, SNAM. To correctly perform such verification a preliminarily setting exercise with the following two key objectives, has been performed: (1) defining clear and consolidated technical acceptance criteria based on the review of the available codes, standards, and literature supported by dedicated considerations made by material and pipeline engineering experts and (2) developing a multi-level methodology whose approach is fine-tuned for each the stages of the repurposing project. During phase 2 of the project the proposed methodology was adopted; a review of SNAM Company Specifications and gap analysis was performed with subsequent assessment of material suitability of approx. 1148 km of existing pipelines operated by SNAM to convey up to 100% of hydrogen. The approach in this document refers to the assessment of the suitability of the pipeline from a materials perspective. Prior to injecting hydrogen into a pipeline, other aspects (e.g., integrity and risk assessment, flow assurance, HSE assessment, etc.) shall be performed in the appropriate project phase; the definition of relevant methodologies is not covered in this document and shall be developed separately.
- Europe > Belgium (0.29)
- North America > United States (0.28)
- Europe > France (0.28)
- Facilities Design, Construction and Operation > Pipelines, Flowlines and Risers > Piping design and simulation (1.00)
- Health, Safety, Environment & Sustainability > Environment > Climate change (0.88)
- Facilities Design, Construction and Operation > Pipelines, Flowlines and Risers > Offshore pipelines (0.68)
- Health, Safety, Environment & Sustainability > Sustainability/Social Responsibility > Sustainable development (0.68)
Hyperbaric Welding and Wire Arc Additive Manufacturing for Downhole Applications in the Oil and Gas Industry
Leon Escobar, Sharen Monserrat (Montanuniversitรคt Leoben) | Walzl, Alexander (Montanuniversitรคt Leoben) | Ravi, Krishna (Montanuniversitรคt Leoben) | Prohaska, Michael (Montanuniversitรคt Leoben) | Stockinger, Martin (Montanuniversitรคt Leoben) | Richardson, Ian Malcolm (IR Welding Consultancy) | Fateh, Nazanin (OMV Exploration & Production GmbH) | Hรถnig, Stefan (OMV Exploration & Production GmbH)
Abstract A large and increasing number of wells must be abandoned or repurposed in the next decades. Additionally, there are many wells to be re-entered and repaired due to problems and conditions such as casing leaks, corrosion, annular communication, patch placement, zonal isolation, closing perforations, etc.; therefore, the development of more efficient and cost-effective methods to address these issues is paramount. The main objective of this research includes the proof of concept (POC) of a Wire Arc Additive Manufacturing (WAAM) process under hyperbaric conditions for downhole applications in the Oil and Gas (O&G) industry. This POC will enable the development of a potential downhole WAAM technology that could place corrosion-resistant steel barriers as well as closing holes in the wellbore. Well plugging and abandonment (P&A), and well integrity re-establishment operations are costly and often associated with a low probability of long-term success. Available conventional technologies and techniques mostly use cement as a plugging material. However, steel has several advantages over cement, such as a higher tensile strength, enabling stronger structures with less material; cement is a brittle material while steel is ductile, steel can also resist higher thermal loads. Additionally, steels can be engineered to withstand harsh environments and resist corrosion. Corresponding lab-scale experiments, simulated in an autoclave solely constructed for the proof of concept of hyperbaric WAAM, are carried out to investigate the fundamentals of this process and material properties for downhole applications. The general project description, laboratory set up and design, including process requirements such as voltage, current, shielding gases, and material properties, are presented. With this proof of concept, an alternative technology will be enabled with the potential to revolutionize wellbore P&A. Once this POC has been proven, the deployment method will be assessed. It is foreseen that some of the benefits of developing such tool will be the introduction of rigless or with smaller workover units P&A operations. Additionally, an entirely new way of applying additive manufacturing is proposed to solve compelling challenges in the O&G industry.
- Europe > United Kingdom (0.93)
- North America > United States > California (0.28)
- Africa > Middle East > Libya > Murzuq District (0.28)
- Research Report (0.46)
- Overview (0.46)
- Africa > Middle East > Libya > Murzuq District > Murzuq Basin > Block NC 186 > Field D Field (0.99)
- Africa > Middle East > Libya > Murzuq District > Murzuq Basin > Block NC 186 > Field A Field > Silurian Tanezzuft Formation (0.99)
- Africa > Middle East > Libya > Murzuq District > Murzuq Basin > Block NC 115 > Field A Field > Silurian Tanezzuft Formation (0.99)
Is Handling Gas in the Riser a Safe Alternative? Exploring the Limits and Opportunities for Safer Kick Handling During Deepwater Drilling
Gabaldon, O. (Blade Energy Partners, Frisco, Texas, USA) | Humphreys, G. (Stena Drilling, Aberdeen, Scotland UK) | Teixeira, M. L. (Equinor, Sandnes, Norway) | Gonzalez-Luis, R. A. (Blade Energy Partners, Frisco, Texas, USA) | Souza, P. (Blade Energy Partners, Frisco, Texas, USA)
Abstract This work complements previous efforts exploring the opportunity for safer return to operations after an influx event in deepwater drilling operations when an MPD system is installed on the floating rig. Additionally, even kicks taken during conventional drilling, with rigs equipped with adequate RGH equipment, can benefit from an alternative way to address the event. An RGH Envelope is proposed, which can be incrementally adopted in a stepwise approach. For MPD operations, influxes greater than IME circulation limits, but within RGH Envelope limits, can be introduced into the riser and then removed using the Fixed Choke, Constant Output (FCCO) method. In non-MPD operations, all influxes need to be initially addressed by shutting the well on the BOP as soon as possible. Then, for influxes within the equivalent MPD IME limits, the surface RGH system can be engaged and routed to the rig choke, and the influx is completely circulated using Driller's method through the riser system. A potential expansion of this method, for influxes exceeding the original IME limits, but within RGH Envelope limits, can be circulated into the riser and then finalized by using FCCO method. For conventional drilling operations without a rotating control device (RCD) seal installed, consideration should be given to installing the seal assembly in the RCD prior to circulating hydrocarbons to surface with an open BOP. The authors explore the RGH Envelope limits and present guidelines for a comprehensive risk assessment on RGH process, limits, and how it impacts multiple aspects of the operations.
- North America > United States (0.97)
- Europe (0.68)
- Well Drilling > Pressure Management (1.00)
- Well Drilling > Drilling Operations (1.00)
- Facilities Design, Construction and Operation > Pipelines, Flowlines and Risers > Risers (1.00)