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Pre-Installed Cable Protectors Will Save Time and Improve Safety While Running Completions
Bibby, J (Vallourec, Aberdeen, Scotland and Vallourec, Aulnoye-Aymeries, France) | Brodie, A (Vallourec, Aberdeen, Scotland and Vallourec, Aulnoye-Aymeries, France) | Fiorucci, J (Vallourec, Aberdeen, Scotland and Vallourec, Aulnoye-Aymeries, France)
Abstract This paper will demonstrate the improved safety advantages, rig time savings and the associated cost reductions available by using pre-installed cable protectors during run-in-hole (RIH) operations for completions where downhole cables are at risk of damage. Pre-installed cable protectors can greatly reduce the number of personnel operating in the ‘red zone’, eliminate costly shipping logistics and reduce the amount of time needed installing cable protectors on the rig floor, thus providing safety benefits and improving RIH timing.
Several companies collect data at the rig, and each company's data acquisition system applies its own timestamp to the data. Subsequent aggregation of data relies on synchronized timestamps which are rarely true. This paper presentation shares the different sources or errors in data time stamping and provides best practices to help mitigate some of these causes.
The Colorado Air Quality Control Commission (AQCC) unanimously approved a rule requiring oil and gas operators to install zero-bleed or zero-emission pneumatic devices for both new and existing operations. Months of negotiations leading to the AQCC rule involved local governments, environmental groups, and industry. "Last year's terrifying wildfires were yet another reminder that climate change is here and local communities across Colorado are suffering the consequences. This collaboration between local governments, environmental groups, and industry will mean less carbon pollution and cleaner, safer air. It is a win for Coloradans all over the state," said Erica Sparhawk, a trustee for the town of Carbondale and president of Colorado Communities for Climate Action, a coalition of 36 local governments across the state.
- Energy > Oil & Gas (1.00)
- Government > Regional Government > North America Government > United States Government (0.52)
Sam Gibbs, the inventor of the wave equation method used in the rod pumping diagnostic and predictive software, and an SPE Legend of Artificial Lift, died 17 February. Gibbs earned his BS in mechanical engineering at Texas A&M University in 1954 and worked for Shell Oil Company briefly before being drafted into the US Army. Upon returning, he took a leave of absence from Shell and went back to school and earned his MS in mathematics at Texas A&M in 1960. Following graduation, he returned to work at Shell and later earned his PhD in mechanical engineering from Rice University in 1968. In 1971, Gibbs formed Nabla Corp. with his friend Ken Nolan, and his contributions revolutionized the oil industry in the field of artificial lift of rod-pumped wells. “We put the Diagnostic Technique in a computer in a truck and hauled it to the well site and did computations right there so we could hand the customer the diagnosis with a completed report right at the well site,” said Gibbs in an interview for JPT, in which he was recognized as a Legend of Artificial Lift in 2014. In 1997, Nabla was sold to Lufkin, which used Gibbs’ patent on downhole card control of pumping wells to create the SAM Well Manager, a control device for rod-pumped wells.
- North America > United States > Texas > Permian Basin > Yeso Formation (0.99)
- North America > United States > Texas > Permian Basin > Yates Formation (0.99)
- North America > United States > Texas > Permian Basin > Wolfcamp Formation (0.99)
- (21 more...)
Cuadrilla Resources has started drilling the UK's first horizontal shale well at its exploration site at Preston New Road, Lancashire, and hopes to begin hydraulic fracturing of two wells in the second quarter. No wells have been fractured in the UK since 2011, when a Cuadrilla well triggered small earthquakes in Lancashire. Advancement of the drilling program comes as the operator recovered data suggesting "excellent rock quality for hydraulic fracturing and a high natural gas content in several zones" of the Bowland shale. Cuadrilla drilled a vertical pilot well to 2.7 km through the Upper and Lower Bowland shale rock intervals, taking 375 ft of core samples from three separate intervals. Wireline logs retrieved data across the entire Bowland shale section.
Methane (CH4), the primary constituent of natural gas and is the second-most abundant greenhouse gas after carbon dioxide (CO2), accounts for 16% of global emissions. The lifetime of methane in the atmosphere is much shorter than CO2, but CH4 is more efficient at trapping radiation than CO2. Pound for pound, the comparative effect of CH4 is more than 25 times greater than CO2 over a 100-year period. Natural-gas emissions from oil and gas facilities such as well sites, refineries, and compressor stations can have significant safety, economic, and regulatory effects. Because of the remote location of many of these facilities, gas emissions can continue for extended periods of time.
- Information Technology > Architecture > Real Time Systems (0.37)
- Information Technology > Communications > Networks > Sensor Networks (0.35)
In the energy transition environment Rock Energy is using hydrocarbon industry business models and oil field technology to enter the geothermal industry in a more direct way where we also operate the asset and provide the end user heat/electricity. In that we start with direct energy wells based on single injection and production wells where the energy user is in proximity of the well site. We use innovative drilling and completion technologies, in combination with multi-physics geophysical imaging to find sweet spots within the normal geothermal gradient background. The produced warm water is used for multiple heating purposes, either as independent standalone systems (heating of surface areas, runways, sport arenas…) or integrated in new or existing district heating systems (office buildings, airports, shopping centers….). Where the return temperatures are high enough, some of the energy output will be in the form of standalone electricity production. An initial project at Gardermoen Oslo airport where 2 wells drilled to 1500 m keeping the engine testing ground ice-free during winter, demonstrate the value of independent energy production close to end users and show considerable potential for replacing electricity usage for heating purposes with clean, green everlasting energy supply. The concept is scalable with regards to energy yields, both by increasing well numbers and the increased energy output by going deeper (higher temperatures – 3000 to 5000 m). The business model is based on developing independent energy plants sold as turnkey projects and/or building, owning and operating assets with long term lease arrangements that produces royalty and leasing revenues. We have identified a large global market for this type of energy production and will extend the business model in the near future to include larger geothermal assets and users internationally. Presentation Date: Monday, October 12, 2020 Session Start Time: 1:50 PM Presentation Time: 2:15 PM Location: 361F Presentation Type: Oral
Digital Oilfield: Review of Real-time Data-flow Architecture for Upstream Oil and Gas Rigs
Sletcha, Ben (Kings Operating Corporation, University of Oklahoma) | Vivas, Cesar (University of Oklahoma) | K. Saleh, Fatemeh (University of Oklahoma) | Ghalambor, Ali (Oil Center Research International) | Salehi, Saeed (University of Oklahoma)
Abstract Advances in horizontal drilling and completion techniques have proliferated onshore development of unconventional shale fields. These wells can span hundreds of miles across a field for a single operator. Live remote monitoring and automation of operations is ideal but rarely cost-effective. Upstream oil and gas operations face many challenges measuring and sending data from remote well sites. Sensors must operate in remote areas, challenging terrain, and inhospitable environments, making very difficult to implement a wireless data flow collection and transmission. Additionally, data integration and consolidation between many devices, software packages, file sizes, and file types, compounds the challenges for analyzing the data for potential improvements in operational efficiencies. Autonomous remote measurement, transmission, and control of oilfield sensors continuously pursued, but rarely fully implemented. The fast production decline of unconventional shales makes high-cost telemetry systems perceived as not economic to install within a few years after the initial production of a well. However, Oil and Gas industry sensors are improving in reliability and become more robust to work in harsh environments. The transmission networks have increased their capabilities and coverage, representing the evolution of every component that conforms the onshore oilfield data architecture, becoming their implementation easier than the recent past. This paper describes the real-time data-flow architecture for oil and gas well operations, and what are the main challenges of implementing the digital oilfield concept by studying the actual use of devices in the field and the conditions in which they operate for understanding the digital oilfield implementation challenges. Also, there are presented some examples of how the industry is benefiting from real-time data-flow architecture and a brief introduction of how it can be connected with big data implementation for enhancing oilfield operations.
- Europe (0.68)
- Asia > Middle East > Saudi Arabia (0.46)
- North America > United States > Texas (0.29)
- North America > Canada > Alberta (0.28)
- Energy > Oil & Gas > Upstream (1.00)
- Government > Regional Government > North America Government > United States Government (0.46)
- Information Technology > Sensing and Signal Processing (1.00)
- Information Technology > Communications > Networks > Sensor Networks (1.00)
- Information Technology > Artificial Intelligence > Representation & Reasoning > Information Fusion (1.00)
- Information Technology > Architecture > Real Time Systems (1.00)
Abstract This paper overviews the application of Lean Six Sigma (L6S) framework and principles to reduce overall cycle time needed to deliver perforation charges for rig-less unconventional well sites. As the unconventional program at Saudi Aramco embarked on a number of shale plays around the Kingdom, the number of fracturing stages increased sharply year on year requiring tremendous efforts to improve operational efficiency. Perforating charges are delivered to rig-less completion sites to be used in multi-stage fracturing of unconventional horizontal wells. These charges are critical for use in several well completion operational applications that are essential for establishing productivity of wells. The perforating charges are inserted in perforation guns or isolation devices, which are lowered to predetermined depths in drilled wells. The tools are subsequently triggered with an electronic signal from the surface controlling cabin to activate the Bottom Hole Assembly (BHA) tools. In an effort to reduce operational Non-Productive Time (NPT), Lean Six Sigma (L6S) was utilized. L6S is a combination of two exclusive expert knowledge areas that were employed to remove excess waste in the business process of delivering perforating charges to well sites (Lean) as well as to improve success prospect in the repetitive operation of perforating charges delivery (Six Sigma). Lean Six Sigma is a proven recipe to substantially enhance business processes through the implementation of a multitude of various tools and methodologies that ultimately aim to achieve predetermined improvement criteria. The deployment of the study's recommendations has subsequently reduced NPT drastically in relation to perforating charges delivery to almost nonexistent levels as detailed in the paper. With the aforementioned increase in the number of stages yearly, the number of well intervention jobs requiring perforating charges is expected to rapidly increase annually due to the high demand for these types of rig-less operations. By reducing NPT, there will be significant cost savings year on year that will be realized as a result of L6S application.
- Energy > Oil & Gas > Upstream (1.00)
- Government > Regional Government > Asia Government > Middle East Government > Saudi Arabia Government (0.56)
Integrated Modeling of the Complex Multilayer Oil, Gas and Condensate Field Development as a Method of the Project Value Increasing
Bogdanov, Evgenii (Gazpromneft Science & Technology Center) | Chameev, Igor (Gazpromneft Science & Technology Center) | Nekhaev, Sergey (Gazpromneft Science & Technology Center) | Badgutdinov, Ruslan (Gazpromneft Science & Technology Center) | Tkachuk, Anton (Gazpromneft, Yamal) | Shorokhov, Aleksei (Gazpromneft, Development)
Abstract The work is devoted to highlighting the experience of creating a full-scale integrated (reservoir – well – infrastructure network) model of gas reservoirs of the large oil, gas and condensate field of Yamal, finding optimal solutions to the problem of both development oil rims, gas caps of productive reservoirs and dry gas reservoirs, as well as the gas injection system on the efficiency of the field development process as a whole. The task included creating, history matching and integration of the hydrodynamic models with surface facility system, the elimination of "bottlenecks" in the gas facility network system and the determination of the optimal solution to the problem of hydrocarbon production (oil production from oil rims and gas production from gas caps and dry gas formations). Conducted integrated calculations allowed us to consistently identify the risks of the project and allowed them to be minimized at the preparatory stage of the project, which leads to an increase in the value of the project.