Mobility Control for Steamflooding With High-Temperature-Resistant Additives

Stoll, Rolf Dieter; Gudenau, Heinrich Wilhelm; Lupik, M.

doi:10.2118/21019-pa

Cited by 7 publications

(5 citation statements)

References 5 publications

(3 reference statements)

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“…This is known from the literature and serves as a confirmation of the consistency of our analysis method compared to other literature references (Stoll et al 1993). We then focus our efforts on new foam boosters (Chabert, Dahanayake, and Morvan 2012) with the objective to determine the kinetics of surfactant degradation under steam foam application conditions.…”

Section: Thermal Stability Of Surfactant Formulationsmentioning

confidence: 66%

Design of Thermally Stable Surfactants Formulations for Steam Foam Injection

Cuenca

Lacombe

Morvan

et al. 2014

Day 1 Tue, June 10, 2014

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Steam injection is currently the most widespread method for heavy oil recovery. However, a serious limitation of this method is its energy cost due to heat losses in the reservoir. Steam foams can be used to increase the apparent viscosity of steam. Such an improvement of steam mobility control optimizes the heat distribution in the reservoir and reduces the impact of reservoir heterogeneities in order to raise oil recovery.Optimized formulations are required to generate stable steam foams in reservoir conditions. This paper presents an original workflow to design efficient combinations of surfactants for steam foam stabilization. The first step is the selection of surfactants demonstrating a good chemical stability at steam temperature, together with a good solubility. The second step consists in evaluating foam stability of these formulations at high pressure and temperature.We study the thermal stability of surfactants using anaerobic screening tests at high temperature. The chemical structure of surfactants is evaluated through quantitative NMR analysis before and after thermal treatment in various conditions (temperatures from 150 to 250°C and durations from 24h to a week). Generated data permit a better understanding of surfactants degradation mechanisms. A customized high pressure/high temperature sapphire view cell is used to investigate the impact of high temperature on the solubility of formulations and to generate foams in reservoir conditions of pressure and temperature. A custom image processing routine is used to measure foam volume as a function of time, in order to evaluate foam stability and rank formulations.We demonstrate the thermal stability of specific surfactants up to 240°C in anaerobic conditions. A strong influence of temperature on foam stability is observed. Our experiments serve as a baseline to design new formulations giving much longer foam stability at 185°C than benchmarks based on alpha olefin sulfonate (AOS) and alkyl aryl sulfonate (AAS). This paper thus aims at providing new insights on steam foam applications with the development of a dedicated surfactant selection workflow and the characterization of new steam foam formulations with improved performances.

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Section: Thermal Stability Of Surfactant Formulationsmentioning

confidence: 66%

Design of Thermally Stable Surfactants Formulations for Steam Foam Injection

Cuenca

Lacombe

Morvan

et al. 2014

Day 1 Tue, June 10, 2014

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“…In order to deal with the problem of "water out in band", steam channeling, low steam quality and wide hot water band, the thermo-chemical combination flooding is proposed (Wang Yudou et al 2001), such as using foaming system for selectively plugging to improve steam swept volume (Stoll 1993 (Figure 8). Because of the characteristics of large well spacing in huff and puff and "concentration in bulk", well pattern is infilled to enlarge the reservoir flow region and to produce the remaining oil in the interwell immobilization zone.…”

Section: Matching Techniques For Enhanced Oil Recovery In the Late Pementioning

confidence: 99%

Advancement and Application of Thermal Recovery Technology in Heavy Oil Reservoir in Shengli Petroleum Province

Sun¹,

2011

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U.S.A., The main features of heavy oil reservoir in Shengli petroleum province are as bellow: (1) deep reservoir (＞1300m), (2) most with active edge and bottom water, (3) thin net pay (＜6m), (4) complicated types. The incremental reserves of heavy oil have low quality in Shengli petroleum province, such as thin net pay, sensitive to water and extra heavy oil reservoirs. The mature fields are going to the development stage characterized by multiple turns of huff and puff, high water cut and low oil producing rate. In this paper, focusing on the bottle-neck and other development technology problems, the novel thermal recovery technologies are studied, such as chemical aided stream drive, water drive turning to thermal recovery and application of horizontal wells in marginal heavy oil reservoir, and thermal chemical huff and puff in extra heavy oil reservoir, in order to improve the heavy oil recovery and low quality reserves effectively developed. The chemicals were designed, the key technological limits were researched, and the composite mechanics of steam, oil displacement and foaming agents were researched in order to improve vertical sweep efficiency of steam drive, flooding efficiency of hot water and low dryness steam flooding recovery in medium and deep heavy oil reservoir. The feasibility of conventional water drive heavy oil reservoir under high pressure and the key technology of water drive transferring to steam drive were studied. The water drive recovery had been significantly improved in conventional heavy oil reservoir. HDCS (horizontal well, dissolver, carbon dioxide and steam) was applied to ultra heavy oil reservoir. The technological limits of horizontal well, new sand control and steam injection technologies were studied in marginal heavy oil reservoir such as thin reservoir, then this type of reservoir were effectively developed and its recovery were improved. Some studies progresses had a breakthrough and were applied in the field. The annual production of thermal recovery increased significantly in Shengli petroleum province. In 2010, the oil production was 4.21 million tons and the increment of low quality reserves developed was 186 million tons and the increment of the recoverable reserves was 59.18 million tons both in mature and new fields. A good economic benefit was obtained.

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“…We defined successful LMOSF projects as those whose average oil rate was increased in at least 30% after three years of steamflooding. The successful LMOSF reservoirs analyzed here are: § Loco, US 9-10 § Yates, US 11 § Georgsdorf , Germany 12-14 § Rühlermoor, Germany 15 § Emlichheim, Germany [16][17][18][19] § Schoonebeek, Netherlands 20-22 § Karamay, China 23-24 § Emeraude, Congo 25-28 § Duri, Indonesia 29-34 § Lacq Supérieur, France [35][36][37][38][39] In addition, the unsuccessful LMOSF reservoir studied are: § Elk Hills, (Naval Petroleum Reserve No. 1), US [40][41][42] § Buena Vista Hills, US [43][44] …”

Section: Field Studiesmentioning

confidence: 99%

“…By the 1970's many fields were benefiting from steamdrive technology; and oil production peaked in the mid 1980's has been fairly constant since 1 . This production had been almost exclusively from the heavy oil reservoirs (10)(11)(12)(13)(14)(15)(16)(17)(18)(19)(20)(21)(22).…”

Section: Introductionmentioning

confidence: 99%

Benchmarking of Steamflood Field Projects in Light/Medium Crude Oils

et al. 2001

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TX 75083-3836, U.S.A., fax 01-972-952-9435. AbstractA benchmarking study on 43 steamflood of light/medium crude oils was performed, to find attractive reservoir characteristics and successful operational practices that are used worldwide. More than 30 successful projects were analyzed and summarized in a database, which included reservoir properties, best operational practices and results obtained. On average, an incremental oil recovery of 19% OOIP was obtained by steamflooding, during a project lifetime of up to seven years.Based on the successful project characteristics, we developed a model to rank potential reservoirs. Reservoir data were analyzed using standard statistical methods for properties, such as: API gravity, initial oil saturation, reservoir temperature, porosity, initial pressure, depth, net pay, viscosity at reservoir condition, initial (at the beginning of steamdrive)bubble pressure ratio and average permeability. The statistical model ranked the properties on a standardized score scale. A predicted score close to one hundred indicates a high probability of success. Supported by this numerical model, we selected the La Salina reservoir (La Rosa Formation, Lake Maracaibo, Western Venezuela) as a potentially successful reservoir to apply steamflood technology.In addition, unsuccessful projects from two different reservoirs (the Naval Petroleum Reserve No.

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Mobility Control for Steamflooding With High-Temperature-Resistant Additives

Cited by 7 publications

References 5 publications

Design of Thermally Stable Surfactants Formulations for Steam Foam Injection

Design of Thermally Stable Surfactants Formulations for Steam Foam Injection

Advancement and Application of Thermal Recovery Technology in Heavy Oil Reservoir in Shengli Petroleum Province

Benchmarking of Steamflood Field Projects in Light/Medium Crude Oils

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