Hydrates amass beneath and around production equipment and can form in hydrocarbon−seawater jets/plumes. The sources of hydrocarbons in these hydrates are natural seeps or temporary production system leaks. In this paper, some of (i) the formation parameters for these hydrates and (ii) the impacts on normal production operations and hydrocarbon-spill capture systems are discussed. ■ INTRODUCTIONChallenges in the design of deepwater production systems include management of hydrates external and internal to the production hardware. This paper focuses entirely on external hydrates. These include hydrates in which the forming-gas sources are near-mudline natural seeps or production fluid leaks. Management of external hydrates is significantly different from internal-hydrates management for two reasons: (1) The goals of external-hydrates management are often quite different from those of internal-hydrates management. For example, external-hydrates management of near-mudline reservoir hydrates seeks to maintain or increase the volume fractions of these hydrates as they contribute to mudline equipment and wellbore stability. (2) The parameter paths along which external and internal hydrates move into the hydrate region are usually different. For example, at a water depth of 5000 ft in the Gulf of Mexico, (a) in an internal steady-state flowing production line with free gas present, (i) liquids are close to gas saturated, (ii) the pressure and temperature decrease as the fluids flow along the line (in the 40°F seawater environment), which can move the system into the hydrate region (see Figure 1), and (iii) the system is far (>30°F) into the hydrate region at 2200 psi and 40°F (see Figure 1), which promotes relatively fast hydrate-formation kinetics. (b) In an external (to the production system) environment with seeps, (i) seawater is near 40°F in temperature and up to 6000 psi in pressure, (ii) seawater is typically under-saturated with gas, and (iii) elevating the seawater dissolved-gas concentration sufficiently to enter the hydrate region can be difficult in locations with ocean currents. (c) In an external (to the production system) environment with rare, temporary leaks, (i) leak−seawater plume temperature decreases from the leak hydrocarbon temperature (e.g., 200°F) to the seawater temperature (∼40°F ) with the distance up from the source, (ii) seawater is typically under-saturated with gas, and (iii) elevating the seawater dissolved-gas concentration sufficiently to enter the hydrate region can be difficult in locations with ocean currents.In other words, the evolution into the hydrate region for internal systems is usually dominated by a decrease in the Figure 1. Hydrate region boundary plot for a system below the bubble point with flowline fluid pressure−temperature trace. Note that the pressure−temperature point at the flowline outlet is more than 30°F inside the hydrate region, which promotes fast hydrate-formation kinetics.Article pubs.acs.org/EF
A review of 289 completions in Ochiltree County, Texas, shows 137 classified gas completions currently produce with the aid of artificial lift. Two methods of artificial lift, beam pumping units and plunger lift, were identified in the review. The study revealed that 130 gas wells produce with the aid of a plunger lift, while only 7 gas wells produce with the aid of a beam pumping unit. This paper reports on historical results obtained from using plunger lift systems. The historical results are compared to published methods for predicting liquid loading and plunger lift production responses. An evaluation of the historical plunger lift production responses and installation workover costs show that an impressive 32 BCF of reserves were added at a cost of less than $0.06/MCF.
Exploration Co.; and K.F. Perry, Gas Research inst. SPE Members .-COw[ght19s4, Socrtiy of Pmroleum Engl"a. r,. Inc. rnls Pij+r was prepaied for presentation !4 tie SPE MId.co.!lnent aia Symwdum held In Amarllo. Tnx=. 22-24 May 1994. This paw was wetted tar prewiatio. by WI SPE Frwam C&mmiuee following review of Mm.tio. Canwmd I. an .Lw.ct su,%inad by Iiw author(s). Comen!s of me P.Q.OW as wsanl.d, hw not been rwwwd by !he society of %tmleum En@ws and WE subject to Conect[on by !he author(s). The mm%rlai. as Pm8..1@ d.e$ Wt ..~$$~W r.flã nyyltic.n of the S.acle!I of Pe!role.m Enginws, (w offlmrs, or members Papers prew.!ed N SPE mmt!.gs am aub]ncl to publkd.m revkw by Etii.atid Committees 01 the Society of wa!eum En@wers Permls$lon to COPY!s restricted to m abstract of n.a mme than w words. Illusuati.ns.may matbe mpiad. i%n .Mrad SII.UU m.t~. Cm$PIC.OUS =~Wwl~9ment of w/km and M whom the Dam, 19 Pmwl!ed, ABSTRACTThis discussion shows the positive results obtained from using state-of-the-art technologies to i@erpret, diagnose, and predict hydraulically fra@@ w_ell..ehsr@eri@icawd responses. Extensive rescrvo~and geological data were collecled and inte~ated into both "reee~oir simulation of production srrd pressure trsn~ent responses and advanced hydraulic fracture m,odeI@gto c&racterize the. C1eveIand formation in the Ellis Randr Field area. The reaulLs showed that vertical proppsnt placement was a critical "Mue and that by making' [he ricesamy adjiitmenk-' to irripr~ve the proppant placement the fracture treatment coats muld be redueed and the prtidictioniekulia improved.
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