scholarly journals METHODS OF INCREASING PROJECT LEVELS OF CRUDE OIL PRODUCTION AT THE DEVELOPMENT OF MULTILAYER DEPOSITS

2017 ◽  
pp. 95-101
Author(s):  
V. V. Panikarovskii ◽  
E. V. Panikarovskii
Keyword(s):  
Hydraulic Fracturing ◽  
Crude Oil ◽  
Enhanced Oil Recovery ◽  
Oil Recovery ◽  
Oil Production ◽  
Injection Wells ◽  
Crude Oil Production

A brief review of the work on intensifying the inflow and increasing the oil recovery of the Neocomian deposits of the Priobskoye field is expounded. The analysis of technologies for increasing oil recovery of AS10, AS11, AS12 is performed. The technology of hydraulic fracturing in production and injection wells and methods of selecting wells for hydraulic fracturing in the operational well stock of the Priobskoye field are considered. Based on the analysis of enhanced oil recovery technologies, the need for hydraulic fracturing in low-productivity reservoirs has been proved.

scholarly journals Design and characterization of a microbial self-healing gel for enhanced oil recovery

RSC Advances ◽  
2017 ◽  
Vol 7 (5) ◽  
pp. 2578-2586 ◽  
Author(s):  
Jun Wu ◽  
Hou-Feng Wang ◽  
Xian-Bin Wang ◽  
Hai-Yang Yang ◽  
Ru-Yi Jiang ◽  
...  
Keyword(s):  
Crude Oil ◽  
Enhanced Oil Recovery ◽  
Oil Recovery ◽  
Oil Production ◽  
Self Healing ◽  
Sweep Efficiency ◽  
The Poor ◽  
Crude Oil Production

Due to the heterogeneity of rock layers, the poor volumetric sweep efficiency of water and an invalid cycle have emerged as major problems in crude oil production.

A Comprehensive Review of Thermal Enhanced Oil Recovery: Techniques Evaluation

2018 ◽  
Vol 141 (3) ◽  
Author(s):  
Esmail M. A. Mokheimer ◽  
M. Hamdy ◽  
Zubairu Abubakar ◽  
Mohammad Raghib Shakeel ◽  
Mohamed A. Habib ◽  
...  
Keyword(s):  
Crude Oil ◽  
Enhanced Oil Recovery ◽  
Oil Recovery ◽  
Oil Production ◽  
Economic Benefits ◽  
Comprehensive Review ◽  
Second Stage ◽  
Energy Demands ◽  
Recovery Techniques ◽  
Third Stage

The oil production from any well passes through three stages. The first stage is the natural extraction of oil under the well pressure, the second stage starts when the well pressure decreases. This second stage includes flooding the well with water via pumping sea or brackish water to increase the well pressure and push the oil up enhancing the oil recovery. After the first and secondary stages of oil production from the well, 20–30% of the well reserve is extracted. The well is said to be depleted while more than 70% of the oil are left over. At this stage, the third stage starts and it is called the enhanced oil recovery (EOR) or tertiary recovery. Enhanced oil recovery is a technology deployed to recover most of our finite crude oil deposit. With constant increase in energy demands, EOR will go a long way in extracting crude oil reserve while achieving huge economic benefits. EOR involves thermal and/or nonthermal means of changing the properties of crude oil in reservoirs, such as density and viscosity that ensures improved oil displacement in the reservoir and consequently better recovery. Thermal EOR, which is the focus of this paper, is considered the dominant technique among all different methods of EOR. In this paper, we present a brief overview of EOR classification in terms of thermal and nonthermal methods. Furthermore, a comprehensive review of different thermal EOR methods is presented and discussed.

scholarly journals Iran’s crude oil reserves and production

GeoArabia ◽  
2007 ◽  
Vol 12 (2) ◽  
pp. 69-94 ◽  
Author(s):  
Moujahed I. Al-Husseini
Keyword(s):  
Crude Oil ◽  
Oil Recovery ◽  
Oil Production ◽  
Improved Oil Recovery ◽  
Total Recovery ◽  
Recoverable Reserves ◽  
Crude Oil Production ◽  
Decline Rate ◽  
The Government ◽  
Giant Fields

ABSTRACT The Government of Iran estimates the country’s initial-oil-in-place and condensate-in-place are about 600 and 32 billion barrels (Gb), respectively. In 2004, the official estimate of the proved remaining recoverable oil and condensate reserves was about 132.5 Gb, of which crude oil accounted for about 108 Gb. Cumulative crude oil production is expected to cross the 60 Gb mark in 2007, implying that the estimated ultimate recoverable reserves of crude oil are about 168 Gb (cumulative production plus remaining reserves) and the total recovery factor is about 28%. The main Oligocene-Miocene Asmari and Cretaceous Bangestan (Ilam and Sarvak) reservoirs contain about 43% and 25%, respectively, of the total crude oil-in-place. Recovery factors for the Asmari range between about 10–60%, and for the Bangestan between 20–30%. Between 1974 and 2004 remaining recoverable reserves have increased from about 66 to 108 Gb, while the ultimate recoverable reserves have increased from 86 to 168 Gb. In contrast to 1974 when Iran’s production peaked at 6.0 Mb/d, production in 2005 averaged about 4.1 Mb/d. The 1974 peak occurred when production from most of the giant fields was ramped-up to very high but unsustainable levels. Current plans are to increase the crude oil production rate to 4.6 Mb/d by 2009. This is a significant challenge because this production capacity has to offset a reported total annual decline rate of 300–500,000 barrels/day (Kb/d). This high decline rate is attributed to the maturity of the giant fields, many of which attained their peaks in the 1970s and have produced about half or more of their estimated ultimate recoverable reserves. Therefore to achieve the 2009 production target within the next three years, Iran has to add about 680 Kb/d of capacity per year from its developed fields (infill drilling, recompletions, enhanced and improved oil recovery), while also adding net new surface facilities and well capacity from undeveloped fields and reservoirs.

scholarly journals ANALISIS PENGGUNAAN LISTRIK ARUS SEARAH UNTUK MENINGKATKAN LAJU PRODUKSI MINYAK BUMI JENIS MINYAK BERAT

2018 ◽  
Vol 9 (2) ◽  
pp. 141-146
Author(s):  
Redaksi Tim Jurnal
Keyword(s):  
Crude Oil ◽  
Direct Current ◽  
Oil Recovery ◽  
Oil Quality ◽  
Electrical Power ◽  
Oil Production ◽  
Heavy Crude Oil ◽  
Technology Application ◽  
Crude Oil Production ◽  
Heavy Crude

rom EEOR, Electro Enhanced Oil Recovery, and a developing technology application which has been established earlier. The difference is ESOR relatively does not improve recovery factor of producing well. Ideally any crude oil producing well will be experiencing pressure decline which may affect crude oil production decrement, naturally. Regarding some similar researches around the world, the use of direct current electrical exposure was proven to increase number of heavy crude oil production. At least salinity, hydrocarbon chemical compounds and crude oil flow in the reservoir (electro-osmosis) involves during chemical processes in the reservoir while ESOR application. Number of electrons conducted from direct current electrical power supply will be a supporting media during chemical process of these parameters. Unfortunately after completing ESOR application in Lapangan X, the result was contradictive with this research hypothesis. Exposure of direct current electrical supply did not increased heavy crude oil production. On a contrary, parameter of salinity and API gravity as produced heavy crude oil quality, were improving significantly.

scholarly journals Solvent Blend Performance in Hydrocarbon Recovery from Nigerian Tank Bottom Sludge

2016 ◽  
Vol 9 ◽  
pp. 20-28 ◽  
Author(s):  
Elijah A. Taiwo ◽  
John A. Otolorin
Keyword(s):  
Crude Oil ◽  
Oil Recovery ◽  
Oil Sands ◽  
Room Temperature ◽  
Oil Production ◽  
Extraction Process ◽  
Improved Oil Recovery ◽  
Hydrocarbon Recovery ◽  
Crude Oil Production ◽  
Tank Bottom

Oil sludge waste associated with crude oil production generally consists of oil, sands and untreatable emulsions segregated from the production stream, and sediment accumulated on the bottom of crude oil and water storage tanks. The use of single solvent and combination (solvent blend) was evaluated for extraction of hydrocarbon content (oil) of the Tank Bottom Sludge (TBS) associated with the crude oil production with a view to optimizing hydrocarbon recovery from the sludge. TBS samples were contacted with selected solvents blends of varying volumetric ratios, each at a time. The blend generated from xylene, hexane, cyclohexane and petroleum ether representing aliphatic and aromatic interactive combination with varying polarity. Their effects on the oil recovery from tank bottom sludge were determined, with solubility parameter as a factor. The optimum oil recovery by blendA,BandCat room temperature of 29°C, from sample 1 are respectively 54.48% (3:2), 60.33% (2:3) and 61.10% (1:1); from Sample 2, were respectively 66.25% (2:3), 60.80 (3:2) and 63.35 (1:1) at room temperature of 29°C . At room temperature BlendChas the highest performance in extracting oil from sample 1. The highest performance in recovery of oil from sample 2 was observed with blendA(66.25 %.). Solvent extraction process is very effective in recovering hydrocarbons oil from TBS. The use of solvents mixture greatly improved oil recovery from TBS and varies with blend composition and the operating temperature condition.

Slowing Production Decline and Extending the Economic Life of an Oil Field: New MEOR Technology

2002 ◽  
Vol 5 (01) ◽  
pp. 33-41 ◽  
Author(s):  
L.R. Brown ◽  
A.A. Vadie ◽  
J.O. Stephens
Keyword(s):  
Enhanced Oil Recovery ◽  
Oil Recovery ◽  
Enhanced Recovery ◽  
Water Injection ◽  
Oil Production ◽  
Oil Field ◽  
Economic Life ◽  
Oil Reservoir ◽  
Injection Wells ◽  
Black Warrior Basin

Summary This project demonstrated the effectiveness of a microbial permeability profile modification (MPPM) technology for enhancing oil recovery by adding nitrogenous and phosphorus-containing nutrients to the injection water of a conventional waterflooding operation. The MPPM technology extended the economic life of the field by 60 to 137 months, with an expected recovery of 63 600 to 95 400 m3 (400,000 to 600,000 bbl) of additional oil. Chemical changes in the composition of the produced fluids proved the presence of oil from unswept areas of the reservoir. Proof of microbial involvement was shown by increased numbers of microbes in cores of wells drilled within the field 22 months after nutrient injection began. Introduction The target for enhanced oil recovery processes is the tremendous quantity of unrecoverable oil in known deposits. Roughly two thirds [approximately 55.6×109 m3 (350 billion bbl)] of all of the oil discovered in the U.S. is economically unrecoverable with current technology. Because the microbial enhanced oil recovery (MEOR) technology in this report differs in several ways from other MEOR technologies, it is important that these differences be delineated clearly. In the first place, the present project is designed to enhance oil recovery from an entire oil reservoir, rather than treat single wells. Even more important is the fact that this technology relies on the action of the in-situ microflora, not microorganisms injected into the reservoir. It is important to note that MPPM technology does not interfere with the normal waterflood operation and is environmentally friendly in that neither microorganisms nor hazardous chemicals are introduced into the environment. Description of the Oil Reservoir. The North Blowhorn Creek Oil Unit (NBCU) is located in Lamar County, Alabama, approximately 75 miles west of Birmingham. This field is in what is known geologically as the Black Warrior basin. The producing formation is the Carter sandstone of Mississippian Age at a depth of approximately 700 m (2,300 ft). The Carter reservoir is a northwest/ southeast trending deltaic sand body, approximately 5 km (3 miles) long and 1 to 1.7 km (1/2 to 1 mile) wide. Sand thickness varies from only 1 m up to approximately 12 m (40 ft). The sand is relatively clean (greater than 90% quartz), with no swelling clays. The field was discovered in 1979 and initially developed on 80-acre spacing. Waterflooding of the reservoir began in 1983. The initial oil in place in the reservoir was approximately 2.54×106 m3 (16 million bbl), of which 874 430 m3 (5.5 million bbl) had been recovered by the end of 1995. To date, North Blowhorn Creek is the largest oil field discovered in the Black Warrior basin. Oil production peaked at almost 475 m3/d (3,000 BOPD) in 1985 and has since declined steadily. Currently, there are 20 injection wells and 32 producing wells. Oil production at the outset of the field demonstration was approximately 46 m3/d oil (290 BOPD), 1700 m3/d gas (60 MCFD), and 493 m3/d water (3,100 BWPD), with a water-injection rate of approximately 660 m3/d (4,150 BWPD). Projections at the beginning of the project were that approximately 1.59×106 m3 oil (10 million bbl of oil) would be left unrecovered if some new method of enhanced recovery were not effective. Prefield Trial Studies The concepts of the technology described in this paper had been proven to be effective in laboratory coreflood experiments.1,2 However, it seemed advisable to conduct coreflood experiments with cores from the reservoir being used in the field demonstration. Toward this end, two wells were drilled, and cores were obtained from one for the laboratory coreflood experiments to determine the schedule and amounts of nutrients to be employed in the field trial.3

scholarly journals Economic Analysis of Gas Reinjection for Enhanced Oil Recovery: A Case Study of the Niger Delta

2020 ◽  
pp. 48-64
Author(s):  
Sampson, Ibinye E. ◽  
Akpabio, Julius U. ◽  
Anyadiagwu, Charles I.
Keyword(s):  
Crude Oil ◽  
Enhanced Oil Recovery ◽  
Oil Recovery ◽  
Niger Delta ◽  
Net Present Value ◽  
Oil And Gas ◽  
Investment Decision ◽  
Petroleum Industry ◽  
Injection Wells ◽  
Production Wells

The instability of crude oil prices at the international market which results in revenue drop to oil and gas operators, the high cost of drilling multiple injection wells and installing gas reinjection systems in a bid to improve recovery of crude oil, have been of great concern to the Petroleum Industry. The Economic viability of Gas Reinjection for Enhanced Oil Recovery (EOR) (as against the gas flaring operation) was analyzed with 7 wells located onshore, in the Niger Delta region of Nigeria. The production history and reservoir data were gathered with which the cost analyses were conducted. Two scenarios involving seven production wells were evaluated. The first was converting two of the production wells to gas injection wells and producing from the remaining 5 production wells (IN2PROD5) and the other was injecting gas in two newly drilled injection wells and producing from the seven production wells (INJ2PROD7). It was shown that (INJ2PROD5) is a preferred option in extending the productive life of an otherwise depleted and uneconomic oilfield, having higher Net Present Value (NPV), Profitability Index (PI) and Internal Rate of Return (IRR) of -$53MM, 0.93 and 27.40% while the INJ2PROD7 had $161MM, 1.39 and 37.75% at discounted rate of 30% respectively. After subjecting the expected net revenues under various crude oil price sensitivity market vagaries, INJ2PROD5 will stand the test of time as it is less expensive and yielded a higher gross profit which is the major factor in any investment decision making.

scholarly journals STUDY OF FILTRATION OF FORMATION FLUIDSAFTER HYDRAULIC FRACTURING

2017 ◽  
pp. 50-54
Author(s):  
S. Y. Abass
Keyword(s):  
Hydraulic Fracturing ◽  
Enhanced Oil Recovery ◽  
Oil Recovery ◽  
Injection Wells ◽  
Selection Of

The technology of conducting hydraulic fracturing in extracting and injection wells and the techniques of selection of wells for hydraulic fracturing in operational fund of wells of Priobskoye field had been reviewed. Based on the conducted analysis of technologies of enhanced oil recovery the necessity of conducting hydraulic fracturing in low-productivity reservoirs was proved.

Creation of the ‘Internet of things’ in crude oil production

2017 ◽  
Vol 10 ◽  
pp. 120-124
Author(s):  
R.S. Khisamov ◽  
◽  
R.A. Gabdrahmanov ◽  
A.P. Bespalov ◽  
V.V. Zubarev ◽  
...  
Keyword(s):  
Internet Of Things ◽  
Crude Oil ◽  
Oil Production ◽  
The Internet ◽  
Crude Oil Production ◽  
The Internet Of Things
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