The solid skeleton of the mudcake consists of fine-grain particles; therefore, a mudcake plug is expected to have a very low permeability and a very good ability to isolate the fracture from wellbore pressure. This requires a relatively permeable formation for two reasons: Mudcake buildup requires fluid loss into the formation, and fracture pressure needs to dissipate after being isolated from the wellbore (Kumar et al. 2010).
The Eagle Ford Shale has reclaimed its standing as one of the most attractive US onshore liquids basins, and for good reason. Does this mean more operators will seek to buy in to the play, and could further consolidation take hold following last year’s big deals? What Happened to all the E&P Deal-Making? One of last year’s big stories in the industry was consolidation among several of the larger upstream operators. But deal activity has fallen off in recent months.
Analytics, sensors, and robots are changing the way one of the world’s largest oil and gas companies does business. Underpinning all the new technology though is a shift in how BP thinks, and what it means to be a supermajor in the 21st century. This paper describes a coreflooding program performed with sandpacks at different permeabilities, water qualities, and injection conditions. In this paper, a new type of sand-consolidation low-viscous binding material, based on a combination of inorganic and organic components, is presented. This paper presents the first successful application of ceramic sand screens offshore Malaysia.
The fourth industrial revolution is taking the oil and gas business by storm. Many companies have increased resources for big-data analytics and machine learning. Though no one sees physical oilfield services as in decline, development in these areas may take a back seat to artificial intelligence. An oil and gas startup has attracted the business with a major operator thanks to its ability to forecast whether production-enhancing chemicals will work as advertised. The evolution of horizontal drilling and multistage completions has changed matrix stimulation from the “more acid, better result” belief to effective lateral distribution and deeper penetration with less acid.
This deal will form the second-largest producer in Colorado’s DJ Basin. The combined company will produce more than 100,000 BOE/D from the Permian Basin and Eagle Ford Shale and is switching its focus to “mega-pad” developments. The deal consists of stakes in nine shallow-water producing fields covering 108,000 gross acres in 10–50 m of water. The combination will create one of the Haynesville Shale’s top gas producers, tripling Comstock’s Haynesville-Bossier acreage. Murphy Oil to Buy Deepwater US Gulf Assets for up to $1.625 Billion The El Dorado, Arkansas-based Murphy has quickly found a home for some of the cash it will receive from the sale of its Malaysia business.
The shale sector is making moves to consolidate amid investor pressure to increase cash flow. This deal will form the second-largest producer in Colorado’s DJ Basin. The combined company will produce more than 100,000 BOE/D from the Permian Basin and Eagle Ford Shale and is switching its focus to “mega-pad” developments. The deal consists of stakes in nine shallow-water producing fields covering 108,000 gross acres in 10–50 m of water. The combination will create one of the Haynesville Shale’s top gas producers, tripling Comstock’s Haynesville-Bossier acreage.
This course discusses the sand control considerations involved in drilling and completing a well to provide candidates with the understanding they need for their own projects. It starts by introducing the various sand control techniques commonly used across the industry, including surface sand handling, rate control, consolidation, standalone screens, gravel packs, high rate water packs and frac-packs. The course then discusses their key design and operational criteria, and explores the remedial options available for wells that were not originally completed with sand control but have started to produce sand. In addition, practical exercises are used throughout to put theory into practice and cement what the attendees have learned. This course is targeted at drilling, completion and production personnel with some sand control experience who are looking to gain a better understanding of sand control completions and operations.
Content of PetroWiki is intended for personal use only and to supplement, not replace, engineering judgment. SPE disclaims any and all liability for your use of such content. Typically resin consolidation (epoxy, furan or phenol-formaldehyde), but may also include sodium silicate, coking, and mineral or metal precipitates.
Resin coated proppant is used in hydraulic fracturing applications to stimulate oil/gas wells for production enhancement. The objective of this study was to perform a rock mechanical study to evaluate long term stability of RCP combined with various additives currently being used in screenless propped hydraulic fracturing completions in the sandstone formations to provide a tool for the industry to know exactly the duration of the shut-in time before putting well back in production. A new experimental method was developed to monitor the curing process of resin-coated proppant as temperature increases. The velocity of both shear and compressional waves were being monitored as a function of temperature. The tested resin of coated proppant sample has been housed in a pressurized vessel. The pressurized vessel was subjected to varying temperature profiles to mimic the recovery of reservoir temperature following propped hydraulic fracturing treatment. The placed proppant should attain an optimum consolidation to minimize proppant flow back.
Historically, sand production from poorly consolidated and unconsolidated sand formation, is a serious problem. These problems can lead to lost reservoir productivity, increased rates of required workover expenditure, fines plugging gravel packs, screens, perforations, tubulars and surface flow lines or separators. These problems hamper hydrocarbon production.
Sand consolidation technology has evolved in recent years to accommodate more rigorous requirements with regards to health and safety, operations, downhole conditions, and high production flow rates. Because of stricter environmental requirements, most operators prefer to apply aqueous-based consolidation treatment fluids instead of solvent-based fluids. However, clay-laden formations can be sensitive to water, and thus the use of aqueous-based treatment fluids is problematic in these formations, especially in those with high clay contents.
This paper presents an aqueous, silane-based resin system for stabilizing and strengthening unconsolidated formation sand surrounding a wellbore. The chemistry of this silane-based treatment fluid was determined to effectively treat large surface areas of formations containing high clay concentrations, while providing high bonding strength between sand grains without plugging their intergrain pore spaces to retain the high permeability of the treated formation. Rather than depending on complete consolidation of formation materials surrounding the wellbore for successful sand control, the new resin enables agglomeration of formation particulates to form aggregates or clusters, thus helping to prevent them from passing through slotted liners or sand screens.
Rock mechanics evaluation of clay-laden sands treated with this new resin system shows that they possess elastic properties and survive the effects of stress cyclic loading. Scanning electron micrographs (SEMs) of the consolidated core material clearly reveal the formation of a porous network of fines and sand, causing little damage to the porosity and permeability of the treated formation. This new resin system provides an alternative to conventional sand control completion in lower quality reservoirs, as well as an effective through-tubing completion alternative. The treatment helps ensure the effectiveness and longevity of standalone screens, thus providing operators with an economical means for well completion.