Practical Steps to Increase Production and Reserves in Mature Gas Fields: Hugoton and Panoma, Texas County, Oklahoma, U.S.A.

Lisigurski, Omar; Rowe, Gregory Charles

doi:10.2118/102259-ms

Cited by 6 publications

(1 citation statement)

References 12 publications

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“…production tubing along with automated unloading programs. 37,38 Challenges are also faced in areas such as the Wilcox formation in south Texas where Y-type completions 39 (see Fig. 2.27) using production tubings of 3-1/2 in.…”

Section: Fig 226-production Tubing Sizes Distribution In Reported Cmentioning

confidence: 99%

Design of a High-Pressure Research Flow Loop for the Experimental Investigation of Liquid Loading in Gas Wells

Fernández

Falcone

Teodoriu

2010

SPE Projects, Facilities &Amp; Construction

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Liquid loading in producing gas wells is the inability of the produced gas to remove produced liquids from the wellbore. A review of existing flow loops worldwide revealed that specialized areas of research such as liquid loading in gas wells are still lacking dedicated test facilities. This project presents the design of a new dedicated facility to be located at the TowerLab at the Richardson building with adequate operating conditions to reproduce the flow regimes encountered prior to and after the onset of liquid loading in gas wells. The facility consists of a compressed air system, pipelines for air and water, a pressure vessel containing glass beads, an injection manifold, and flow control and monitoring devices.Our results show that three compressors working in parallel is the most technical and economic configuration for the TowerLab based on the overall costs provided by the supplier, the footprint but most importantly the flexibility. The design of the pressure vessel required a cylindrical body with top and bottom welded-flat head covers with multiple openings to minimize its weight. The pipelines connecting major equipment and injection manifold located at the pressure vessel were selected based on the superficial velocities for air and water. These values also showed the need for independent injection using two manifolds instead of commingling flow through a tee joint. The use of digital pressure gauges with an accuracy of 0.05 to 25% and coriolis or vortex meters to measure air flowrate is also suggested.

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Section: Fig 226-production Tubing Sizes Distribution In Reported Cmentioning

confidence: 99%

Design of a High-Pressure Research Flow Loop for the Experimental Investigation of Liquid Loading in Gas Wells

Fernández

Falcone

Teodoriu

2010

SPE Projects, Facilities &Amp; Construction

View full text Add to dashboard Cite

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Characterization of small scale heterogeneity to predict acid fracture performance

Oeth¹,

Hill²,

Zhu³

et al. 2013

Journal of Petroleum Science and Engineering

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Unique Methodology for Well Re-entries Requiring Sand Control Improves Production Potential

Penno

Fitzpatrick

Garrison

2007

SPE Offshore Europe Oil and Gas Conference and Exhibition

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In re-entry or workover type situations, the primary performance objectives determined during the initial well completion remain the same, especially in deepwater, high-rate wells. These generally require running the largest-diameter casing string possible, since the dimensions of the completion equipment can determine critical well objectives. Especially in reservoirs requiring sand-control reliability, production rate becomes a primary concern in the workover situation. Issues regarding critical erosional velocities, reservoir sweep or recovery efficiency and feasibility of installing flow controls or intelligent-well equipment remain. For mature wells requiring a side-track, the current well-construction practices necessitate reduced dimensions of the sand-control completion-equipment. This paper presents a well construction/completion methodology that supports increased completion-component dimensions in side-tracked or new wells, potentially improving overall well performance. The system is suitable for any openhole gravel-pack completion. Introduction Because of the prevailing high prices of hydrocarbons and the difficulty in finding new reserves, the oil and gas industry has made efforts to increase the rates of recovery in mature fields. The average rate of recovery is 35% for oil and 70% for gas; however, the current direction is to try to increase the recovery rate of oil to 50% and more than 80% for gas.1 Mature fields — also called brown fields1 — are those oil and/or gas fields that are approaching the end of their productive life. Typically, these mature fields have been producing for more than 30 years and are located in certain geographical areas for different historical and geopolitical reasons. Brownfields are commonly located in the North Sea, United States (onshore), South America, Russia and Australia. These fields produce over 70% of the world's oil and gas production. Brownfields possess the advantage of an existing infrastructure, providing the least expensive means to increase reserves and production. In both enhanced reserves recovery projects for mature fields using sidetracks from existing wellbores and for new well field development projects, wellbore size and casing design requirements are key determinants for well construction costs. Yet, wellbore size and tubulars designs must be balanced against cost factors in order to accommodate certain critical requirements, including:rig- and drilling-equipment limitationssub-sea preventer stack dimensionsexisting wellbore geometry and trajectory limitations for sidetrackstubular sizing needed for reservoir productivityhole size needed to accommodate gravel-pack completionscasing size needed for downhole flow-control equipmentcasing size needed for artificial-lift equipment. Oil fields developed for openhole deviated or openhole lateral gravel packs typically install and cement production casing or liners. The openhole production interval is then drilled using the next smaller bit size. The single-trip method described in this paper is more cost efficient in that it does not require changing hole sizes and eliminates at least one pipe round trip. In this new method, the production liner and hanger are combined with the openhole gravel pack assembly and run into the well in a single trip. The gravel-pack service tool and accessory equipment is configured to allow gravel packing and liner cementing in consecutive operations within the same pipe trip. In this paper, a system, which targets an economical increase in production and reserves in mature unconsolidated reservoirs/fields, is described. The methodology accomplishes these achievements through using:Larger screen ODs, which improve flow area and screen life, thereby increasing productionMinimized pipe trips, which impact completion costs by saving rig time and wearA one-shot deployment of liner and screen with an option of gravel packing and liner cementation.

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Practical Steps to Increase Production and Reserves in Mature Gas Fields: Hugoton and Panoma, Texas County, Oklahoma, U.S.A.

Cited by 6 publications

References 12 publications

Design of a High-Pressure Research Flow Loop for the Experimental Investigation of Liquid Loading in Gas Wells

Design of a High-Pressure Research Flow Loop for the Experimental Investigation of Liquid Loading in Gas Wells

Characterization of small scale heterogeneity to predict acid fracture performance

Unique Methodology for Well Re-entries Requiring Sand Control Improves Production Potential

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