A new paper from ADI Analytics examines the circumstances in which natural gas could become an attractive method for fueling oilfield equipment. These balls have the potential to alter how pipeline inspections are done, and a consortium of pipeline operators and industry experts in North Dakota is examining just how well this emerging technology can handle the small-diameter pipelines in the area. The CEO of Phillips 66 expects the DAPL to be operational in 2Q 2017. The Dakota Access Pipeline, which will connect the Bakken and Three Forks production areas, has received the regulatory go-ahead from the US Army Corps of Engineers. This article explores the outlook for the global market and gives insight into technology trends and the regions that hold the biggest opportunities for water treatment.
A pilot project carried out by Hess demonstrates how quickly automated drilling technology is able to take a rig from the bottom of the pack in terms of performance and push it to the top. The Bakken Petroleum System, which includes the Bakken and Three Forks shales in North America, is estimated to hold as much as 900 billion bbl of original oil in place. As shale operators look for ways to survive amid the current downturn in oil prices, accelerating the refracturing of older horizontal wells is turning into one of the most attractive options. More than 21 billion bbl of light, sweet crude oil will be extracted over the lifetime of the Bakken and Three Forks shale plays, according to the latest projections from energy consultancy group Wood Mackenzie.
From the highest courts of the US judicial branch to the C-suite, contests involving patents have recently come to the fore in the innovation hungry US oilfield services industry, even as filings and litigation have declined in recent years. Seeking out, experimenting with, and ultimately embracing technologies from other industries have proven crucial to innovating at oilfield service firms such as Halliburton, which has tried everything from dog food to submarine tech to improve its work downhole. R&D may be the key to the survival of companies as the new economics of the industry take hold. The R&D Technical Section dinner at ATCE drew varying perspectives as the panelists discussed, and sometimes debated, a range of approaches to safeguarding industry viability and growth in the years ahead. Even as the oil and gas industry looks for the next great idea to propel it forward, it should constantly reconsider past innovations for inspiration, the CEO of a major operator said Monday on the opening day of 2017 SPE ATCE.
This paper covers the staged field-development methodology, including analysis and evaluation of various development concepts, that enabled the company to optimize both completion design and artificial-lift selection, reducing downtime and lowering operating costs by nearly 50%. The First Eocene is a multibillion-barrel heavy-oil carbonate reservoir in the Wafra field, located in the Partitioned Zone between Saudi Arabia and Kuwait. After more than 60 years of primary production, expected recovery is low and provides a good target for enhanced-oil-recovery processes. This paper studies the technical and economic viability of this EOR technique in Eagle Ford shale reservoirs using natural gas injection, generally after some period of primary depletion, typically through long, hydraulically fractured horizontal-reach wells. This paper provides a robust methodology for miscible CO2 WAG experimental-data acquisition and history matching.
High-fidelity 3D engineering simulations are valuable in making decisions, but they can be cost-prohibitive and require significant amounts of time to execute. The integration of deep-learning neural networks with computational fluid dynamics may help accelerate the simulation process. The pipeline system will have the initial capacity to deliver 150,000 B/D of crude oil to multiple delivery points, accessing local refineries and connecting to several downstream pipelines. The independent oil and gas company is aiming to build shareholder value through a change in business focus to midstream with this step into pipeline service and construction. Phase 1 of the development today marked the sail-away from Kværner’s yard of the 560-bed living-quarters topside, the largest of its kind in Norway.
The oilfield services sector showed steady revenue growth in 2018 thanks, in part, to increased project sanctioning. With the oil price falling $20 in the past 2 months, however, the future may be murkier than expected. API released an updated valve standard for wellhead and tree equipment, which includes new automatic closure requirements. Researchers from Chevron are looking into a new approach to understand the drivers of polymer hydration. How might this affect the design of mixing systems in the field, and could it affect offshore EOR applications?
In the shale oil business, cash flow is a life or death issue. For smaller players, money from investors and lenders is getting harder to find. Keen on Anadarko for a while, Occidental Petroleum is ready to do battle with Chevron for the big independent. What Happened to the Private, Family-Owned Oil Company? When the oil and gas industry goes one way, family-owned Hunt Oil goes the other.
Houston-based Surge Energy drilled the Medusa Unit C 28-09 3AH well in the Midland Basin to a TMD of 24,592 ft, with a total horizontal displacement of 17,935 ft, or 3.4 miles. Wadhah Al-Tailji, technical manager at StrataGen, shares his latest technical reads. What Happened to the Private, Family-Owned Oil Company? When the oil and gas industry goes one way, family-owned Hunt Oil goes the other. And that’s why the company has been around for three generations.
More than 250 industry leaders highly involved in Arctic E&P gathered for the 2018 Arctic Technology Conference recently in Houston. Earlier this year in Aberdeen many of the oil and gas industry’s innovation champions met to discuss the developments that are driving the digital transformations within operators and service providers alike. The digital transformation of the oil and gas industry dominated discussion at the 2018 SPE Annual Technical Conference and Exhibition held in late September in Dallas. The SPE Liquids-Rich Basin Conference in Midland, Texas, merged topics that have dominated recent industry discussions: technologies centered on big data, interwell communication, and Permian Basin production. A new event is kicking off in September that will bring together the brightest minds in digital tech and oil and gas.
He, Youwei (China University of Petroleum, Beijing and Texas A&M University) | Chai, Zhi (Texas A&M University) | Huang, Jingwei (Texas A&M University) | Li, Peng (China University of Petroleum) | Cheng, Shiqing (China University of Petroleum) | Killough, John (Texas A&M University)
Although hydraulic fracturing enables economic production from tight formations, production rates usually decline quickly and result in low hydrocarbon recovery. Moreover, it is difficult for conventional flooding methods to provide enough energy supplement in the tight formations. This paper develops an innovative approach to enhance oil recovery from tight oil reservoirs through inter-fracture injection and production, including synchronous inter-fracture injection-production (SiFIP) and asynchronous inter-fracture injection-production (AiFIP). This improves flooding performance by transforming fluid injection between different wells to between adjacent fracture stages from the same horizontal well.
The multi-stage fractured horizontal well (MFHW) comprises of recovery fractures (RFs), injection fractures (IFs) and natural fractures. In all the cases demonstrated in this work, the odd fractures and even fractures are defined as RFs and IFs respectively. Fluid is injected into IFs from injection tubing, and hydrocarbon is recovered synchronously or asynchronously through oil tubing connecting to the RFs. To quantitatively evaluate the performance of SiFIP and AiFIP in tight oil reservoirs, reservoirs are simulated based on the compartmental embedded discrete fracture model (cEDFM). The production performance of different recovery methods is compared, including primary depletion, water flooding, CO2 flooding, water Huff-n-Puff, CO2 Huff-n-Puff, SiFIP (water), SiFIP (CO2), AiFIP (water), AiFIP (CO2). The AiFIP and SiFIP achieve higher cumulative oil production than other methods. AiFIP obtained the highest cumulative oil production, which is more than two times that of primary depletion. The AiFIP (CO2) obtained almost the same cumulative oil production with SiFIP (CO2) with only 50% of CO2 injection rates, and AiFIP (water) obtained 19.3% higher cumulative oil production than SiFIP (water) with only 50% of water injection rates. Therefore, AiFIP is also a better choice when CO2 or water resource is not abundant. Sensitivity analysis is carried out to discuss the impacts of fracture and injection parameters on cumulative oil production. The fracture spacing, fracture networks, and injection rates influence the production significantly, followed by injection-production schedule and fracture length. The recommended well completion schemes of AiFIP and SiFIP methods are also provided, which is significant for the potential application of the proposed methods. This work illustrates the feasibility of SiFIP and AiFIP to enhance hydrocarbon recovery in tight reservoirs.