Weight Down System for Floaters

Ross, Colby M.; Roane, Tom

doi:10.2118/73774-ms

Cited by 7 publications

(1 citation statement)

References 19 publications

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“…Several state-of-the-art technologies were instrumental in the success of this completion and gravel packing procedure . The equipment innovations included special packer technology, a multi-position weight down tool with a horizontal gravel pack (HZGP) pressure maintenance assembly, 5 and a new type of sand control screen. The proprietary pressure maintenance assembly provided a continuous flow path through the packer assembly in order to maintain a constant hydrostatic pressure on the wellbore while running the completion, thus controlling borehole integrity.…”

Section: Introductionmentioning

confidence: 99%

New Technologies Enhance Operational Efficiency in Difficult Gravel-Pack Operations

Lima

Pounds

Borin

et al. 2004

SPE Asia Pacific Oil and Gas Conference and Exhibition

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Although extended reach and horizontal wells in deepwater fields have presented many difficult challenges, operators have been willing to accept the challenges because of the substantial net reserves that the deepwater fields offer. Unfortunately, although promising new technologies that target the more extreme conditions inherent to deepwater completions have been introduced, many operators have hesitated to try them because they lack proven track records. Fortunately, this has not been the case with one operator, and this paper will discuss the innovative technologies that were employed to successfully perform two "firsts" in gravel pack completions in complicated wellbore scenarios in a deepwater subsea field.The first job is the longest deepwater horizontal gravel pack (HZGP), run in Brazil. 75,000 pounds of gravel was placed in a 2,730-ft openhole section in 2,621 ft of water from the Ocean Alliance rig.The technologies that were instrumental in the success of this completion included special packer technology, a multi-position weight down tool with a HZGP pressure maintenance assembly, and a new type of sand control screen. Despite the long slant section (6560 ft @ 60 degrees) and openhole length, installation of the sand control completion was smooth, never reaching more than 10,000 pounds of drag.The second job used a realtime operations (RTO) data acquisition and visualization system during a gravel pack procedure. The system employs advances in traditional data management and networking to allow the personnel at the wellsite as well as all remotely stationed personnel to monitor critical well parameters so that immediate decisions on procedural changes can be made. The system allowed the service personnel and operator to monitor the job's execution and adjust pumping parameters as needed. This job illustrates the enhanced capabilities that can be gained from adapting innovative techniques to traditional procedures. Producing the fields is a massive undertaking and will add 30% to the current one million BOPD output from the area. The development project includes 55 wells of which 22 will be horizontal producers, 2 multilateral producers, 8 horizontal injectors, and 8 piggyback injectors. The 15 wells already in production will be recompleted.

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Section: Introductionmentioning

confidence: 99%

New Technologies Enhance Operational Efficiency in Difficult Gravel-Pack Operations

Lima

Pounds

Borin

et al. 2004

SPE Asia Pacific Oil and Gas Conference and Exhibition

View full text Add to dashboard Cite

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Critical Data Needs for Design of Frac-Pack Completions in Today's Oilfield Environment

Moreno

Haydell

Landry

2009

SPE Offshore Europe Oil and Gas Conference and Exhibition

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In an unconsolidated environment, operators often employ frac-packs to stimulate the reservoir as well as to provide sand control. If the frac-pack is designed and applied correctly, the stimulation will not only increase the recovery of reserves and reduce drawdown, but the sand control will remain effective for a long period of time. With rig costs presently as high as $600 thousand or more per day, reducing workover needs is a major consideration in today's oilfield environment. This paper discusses the crucial design requirements for a frac-pack installation and why accurate reservoir data is critical to the effectiveness of both the pumping and completion aspects of the design. In the past, assumptions on reservoir information for the frac-pack were often based on historical data and conventional fracturing theories because relevant reservoir information was not available. Following these design parameters often provided inconsistent results that did not meet the intended goals, especially in deeper, higher-pressure environments. Moreover, since frac-pack has now become one of the most common methods used in sand-control completions, and development has moved into deeper, more complicated environments, it is even more critical that the essential tools and data required to meet the operator's goals be used in order to design the frac-pack completion. This paper will discuss the well parameters and other critical information that enables frac-pack completions to be designed to meet today's more critical reservoir, safety, and cost-efficiency needs. Introduction The use of frac-pack completions has increased in many areas of the world, and one of its main growth areas has been in deepwater development, which is now adjacent to several continents. Deepwater attracts operators that vary from majors to mid-size independents. Even with the high levels of investment essential for this type of development, the production possibilities make these developments very attractive. The operating costs in deepwater are extreme and require great care in planning and design of frac-pack completion installation. Certain data must be acquired if the following needs, which are critical to success, are to be met:Improved design efficiency and reliabilityOptimization of the stimulation treatment to improve well productivityPrediction of possible outcomes for the frac-pack treatmentReduction of job planning timeReduction of location time spent to redesign or resolve on-site problemsDevelopment of the most accurate models of what happens downhole. Although many of the technical and environmental issues regarding frac-pack completions remain the same between deepwater and non-deepwater applications, their implication is magnified in deepwater due to their typical size and cost; (Richardson et al, 2008). The ultimate objectives, which are to maximize well productivity and recovery through the initial completion, are the same and can only be obtained through completion and frac-pack reliability. A frac-pack provides two main benefits to an operator - stimulation and sand control. If the frac-pack is applied correctly, it can help to stimulate a well and allow for greater production with less drawdown as well as increased recovery of reserves. While these benefits can vary depending on the well conditions, in most cases, the frac-pack will enhance production, if the treatment is optimized. There are many factors and software programs that are used to determine how greatly the treatment can affect the formation. At a minimum, the fracture will bypass near-wellbore damage, and thus, bringing the formation closer to its original skin values.

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Deepwater Frac-Pack Maximum Treating Pressure Limits, An Examination Using BottomHole Pressure Gauges

Lizak

Hinnant

2011

SPE Drilling &Amp; Completion

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Summary During frac-pack treatments, completion hardware is often subject to extreme differential pressures. This is especially true during early screenouts where the large hydrostatic differentials can suddenly be placed on the completion components, resulting in a high risk of collapse. Deep wells and completion-tool configuration can limit supporting pressures for these tools. To prevent damage to completion hardware such as crossover tools, fluid-loss devices, and blank pipe, the maximum surface treating pressure has been limited to a calculated Pmax (Jannise and Edwards 2007). Conventionally, the reservoir pressure was used as the internal supporting pressure in these calculations. Using the reservoir pressure to calculate the Pmax results in a worst-case pressure limit that prevents collapse in virtually any job. However, today many frac-pack treatments are being performed in low-pressure, subhydrostatic reservoirs. Many of these jobs could not be placed using just reservoir pressure for support, even when using high-strength, completion hardware materials. By analyzing a significant number of actual jobs, it was determined that the current standard equations are too conservative when compared to actual treating results. By using less conservative, modified equations, numerous additional wells have been completed with frac-pack technology. This paper studies a number of these successful frac-pack jobs that could not have been performed using the standard Pmax equation and safety factors. Postjob bottomhole-gauge data are examined to determine the true differential pressures and verify the accuracy of the assumptions that are used in the modified Pmax calculation, which provides valuable insight and recommendations for tool design, fluid properties, and maximum-pressure limitations for frac-pack completions.

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Weight Down System for Floaters

Cited by 7 publications

References 19 publications

New Technologies Enhance Operational Efficiency in Difficult Gravel-Pack Operations

New Technologies Enhance Operational Efficiency in Difficult Gravel-Pack Operations

Critical Data Needs for Design of Frac-Pack Completions in Today's Oilfield Environment

Deepwater Frac-Pack Maximum Treating Pressure Limits, An Examination Using BottomHole Pressure Gauges

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