The Juliet Field, Block 47/14b, UK North Sea

AbstractThe abandoned Juliet gas field is a small, highly compartmentalized, accumulation situated south and east of the Amethyst Gas Field. It was discovered in 2008 by well 47/14b-10 and flowed first gas on 5 January 2014. The field consists of at least two culminations within a very low-relief east–west-orientated fault-bounded anticline. The reservoir comprises aeolian sandstones of the Permian, Rotliegend Group, Leman Sandstone Formation. Reservoir quality varies from good to moderate, with a high production rate achieved from horizontal wells.Seismic time-to-depth conversion is affected by Quaternary seabed channels, chalk burial history and a rapid thickening in the Basalanhydrit Formation located over the east of the field, associated with the edge of the Zechstein Basin.Gas-in-place at pre-development was expected to be 105 bcf, with reserves of 67 bcf. The field was developed using two horizontal wells and a subsea tie-back to the Pickerill Field, 22 km to the east. Since development, the field appears to be more compartmentalized than initially expected.

Download Full-text

The Amethyst Field, Blocks 47/8a, 47/9a, 47/13a, 47/14a, 47,15a, UK North Sea

Geological Society London Memoirs ◽

10.1144/gsl.mem.1991.014.01.48 ◽

1991 ◽

Vol 14 (1) ◽

pp. 387-393 ◽

Cited By ~ 4

Author(s):

C. R. Garland

Keyword(s):

North Sea ◽

Reservoir Quality ◽

Geological Model ◽

Gas Field ◽

Seismic Parameters ◽

Recoverable Reserves ◽

High Production ◽

Sandstone Formation ◽

Phased Development ◽

Overlying Strata

AbstractThe Amethyst gas field was discovered in 1970 by well 47/13-1. Subsequently it was appraised and delineated by 17 wells. It consists of at least five accumulations with modest vertical relief, the reservoir being thin aeolian and fluviatile sandstones of the Lower Leman Sandstone Formation. Reservoir quality varies from poor to good, high production rates being attained from the aeolian sandstones. Seismic interpretation has involved, in addition to conventional methods, the mapping of several seismic parameters, and a geological model for the velocity distribution in overlying strata.Gas in place is currently estimated at 1100 BCF, with recoverable reserves of 844 BCF. The phased development plan envisages 20 development wells drilled from four platforms, and first gas from the 'A' platforms was delivered in October 1990. A unitization agreement is in force between the nine partners, with a technical redetermination of equity scheduled to commence in 1991.

Download Full-text

Ravenspurn South Field, Blocks 42/29, 42/30, 43/26, UK North Sea

Geological Society London Memoirs ◽

10.1144/gsl.mem.1991.014.01.58 ◽

1991 ◽

Vol 14 (1) ◽

pp. 469-475 ◽

Cited By ~ 4

Author(s):

R. D. Heinrich

Keyword(s):

North Sea ◽

Reservoir Quality ◽

Desert Environment ◽

Gas Field ◽

Field Development ◽

Southern North Sea ◽

Fluvial Processes ◽

Sandstone Formation ◽

Aeolian Sands

AbstractThe Ravenspurn South Gas Field is located in the Sole Pit Basin of the Southern North Sea in UKCS Block 42/30, extending into Blocks 42/29 and 43/26. The gas is trapped in sandstones of the Permian Lower Leman Sandstone Formation, which was deposited by aeolian and fluvial processes in a desert environment. Reservoir quality is poor, and variations are mostly facies-controlled. The best reservoir quality occurs in aeolian sands wth porosities of up to 23% and permeabilities up to 90 md. The trap is a NW-SE-striking faulted anticline: top seal is provided by the Silverpit Shales directly overlying the reservoir, and by Zechstein halites. Field development began early in 1988 and first gas was delivered in October 1989. Production is in tandem with the Cleeton Field, about 5 miles southwest of Ravenspurn South, as the Villages project. Initial reserves are 700 BCF and field life is expected to be 20 years.

Download Full-text

The Sean fields, Block 49/25a, UK North Sea

Geological Society London Memoirs ◽

10.1144/m52-2019-11 ◽

2020 ◽

Vol 52 (1) ◽

pp. 255-261 ◽

Cited By ~ 1

Author(s):

R. J. Botman ◽

J. van Lier

Keyword(s):

North Sea ◽

Reservoir Quality ◽

Late Permian ◽

High Recovery ◽

Gas Field ◽

Sandstone Formation ◽

Gas Fields

AbstractBlock 49/25a contains the Sean gas fields, Sean North, Sean South and Sean East – collectively known as the Greater Sean area and discovered in 1969. The fields are located in the Southern Gas Basin, about 15 km SE of the Indefatigable gas field. Approximately 1.1 tcf of gas is trapped in a series of fault-bounded dip closures consisting of Permian sandstones belonging to the Leman Sandstone Formation (Rotliegend Group). The reservoir is overlain by evaporites of the Late Permian Zechstein Group. The fields are characterized by excellent Leman reservoir quality, and resources have increased significantly over the years. The reservoir largely behaves as a well-connected tank, which has resulted in high recovery factors (>90%).In 2015, Oranje-Nassau Energie UK Ltd (ONE) took over operatorship of the field through purchasing the rights of both Shell and Esso, giving ONE a 50% operated interest together with SSE E&P UK Ltd (SSE). In 2017, an infill well (SSPD05) was drilled by ONE to test a pop-up structure situated between Sean North and Sean South. The well found, as expected, partially depleted reservoir but has proven to accelerate production and add incremental reserves to the field.

Download Full-text

Staged-Fracturing Completion Technology for the Ultra Deep-Hpht High Inclination Well in the Keshen Gas Field: a Case Study

10.2118/202108-ms ◽

2021 ◽

Author(s):

Kelin Wang ◽

Yan Wang ◽

Hongtao Liu ◽

Xinxing He ◽

Shuang Liu ◽

...

Keyword(s):

Production Rate ◽

Axial Force ◽

Maximum Flow ◽

Geological Structure ◽

Gas Field ◽

Systematic Analysis ◽

High Production Rate ◽

Key Factor ◽

High Production ◽

Pump Pressure

Abstract Keshen No. 10 gas reservoir has a large amount of resources, but the geological structure is complex, and three sets of faults are developed in the upper formation. Four vertical wells had been drilled in the last ten years, and only one well was drilled successfully. To develop the gas field, a high inclination well KSX was designed to avoid the faults. The final well depth is 7060m, maximum inclination was 76.6°, reservoir pressure was 103MPa, reservoir temperature was 154 °C, effective reservoir thickness was 115.5m, and the production casing was 7 3/4 inch with 5 inch liner. The staged-fracturing was designed to achieve a high production rate, and it was a major challenge for completion design and operation. To meet the requirement of staged fracturing, the different completion technology including bridge plug isolation, packer isolation and temporary plugging of perforated intervals were evaluated, and the combination of packer isolation and temporary plugging was finally chosen. Based on the casing program, 7 3/4 inch + 5 inch double packer combination was chosen preferably. Also, systematic analysis was conducted for the past failure case of double packer fracturing in the HPHT well, and it was clear that excessive axial force was the key factor of packer failure. Therefore, expansion joint was set between the packers to relieve the axial force on the packer during the fracturing. In addition, the soluble ball was chosen to open the sliding sleeve to conduct the next interval fracturing operation. During the completion operation, wellbore treatment, packer centralization and the other auxiliary measures were taken, completion string was successfully run in the expected depth, and the packer setting was also normal. During the fracturing operation, the target intervals were divided into two zones by both soluble ball and packers, the fiber temporary plugging of perforated intervals were completed in each zone, and the temporary pressure was up to 7 MPa. The total injection fluid volume 2562m3, total sand volume 159m3, maximum flow rate 6.55 m3/min, maximum pump pressure 118.5MPa. After fracturing operation, the production rate 740,000 m3/d was obtained with wellhead flow pressure 75MPa, and the rate was 2.6 times larger than the vertical well.

Download Full-text

Isotope separation of 176Lu a precursor to 177Lu medical isotope using broadband lasers

Scientific Reports ◽

10.1038/s41598-021-85414-z ◽

2021 ◽

Vol 11 (1) ◽

Author(s):

M. V. Suryanarayana

Keyword(s):

Production Rate ◽

Isotope Separation ◽

Medical Applications ◽

Optimum Conditions ◽

High Production Rate ◽

Laser Isotope Separation ◽

High Production ◽

System Requirements ◽

Medical Isotope ◽

Rhodamine Dye

AbstractA new photoionization scheme accessible by Rhodamine dye lasers is proposed for the isotope separation of 176Lu.$$5d6s^{2}\,{^{2}D_{{3/2}}} (0.0\, {\text{cm}}^{{ - 1}} )\mathop{\longrightarrow}\limits^{{573.8130\, {\text{nm}}}}5d6s6p\,{^{4}F_{{3/2}}^{o}} \left( {17427.28\, {\text{cm}}^{{ - 1}} } \right)\mathop{\longrightarrow}\limits^{{560.3114\, {\text{nm}}}}$$ 5 d 6 s 2 2 D 3 / 2 ( 0.0 cm - 1 ) ⟶ 573.8130 nm 5 d 6 s 6 p 4 F 3 / 2 o 17427.28 cm - 1 ⟶ 560.3114 nm $$6s{6p}^{2}\,{^{4}{P}_{5/2}}\left(35274.5 \,{\text{cm}}^{-1}\right){\to } Autoionization\, State {\to }{Lu}^{+}$$ 6 s 6 p 2 4 P 5 / 2 35274.5 cm - 1 → A u t o i o n i z a t i o n S t a t e → Lu + Optimum conditions for the laser isotope separation have been theoretically computed and compared with the previously reported work. The enrichment of ~ 63% can be obtained with > 22 mg/h production rate even when broadband lasers with bandwidth of 500 MHz are employed for the two step excitation. The simplified system requirements for the photoionization scheme combined with a high production rate of 176Lu than previously reported is expected to reduce the global shortage of 176Lu isotope for medical applications.

Download Full-text

Can Frequency Account for the Grammatical Choices of Children and Adults in Nominal Modification Contexts? Evidence from Elicited Production and Child-Directed Speech

Languages ◽

10.3390/languages6010035 ◽

2021 ◽

Vol 6 (1) ◽

pp. 35

Author(s):

Emanuela Sanfelici ◽

Petra Schulz

Keyword(s):

Language Acquisition ◽

Production Rate ◽

Relative Clauses ◽

Language Use ◽

Spontaneous Speech ◽

Production Task ◽

Specific Context ◽

High Production Rate ◽

High Production ◽

Acquisition Order

There is consensus that languages possess several grammatical variants satisfying the same conversational function. Nevertheless, it is a matter of debate which principles guide the adult speaker’s choice and the child’s acquisition order of these variants. Various proposals have suggested that frequency shapes adult language use and language acquisition. Taking the domain of nominal modification as its testing ground, this paper explores in two studies the role that frequency of structures plays for adults’ and children’s structural choices in German. In Study 1, 133 three- to six-year-old children and 21 adults were tested with an elicited production task prompting participants to identify an agent or a patient referent among a set of alternatives. Study 2 analyzed a corpus of child-directed speech to examine the frequency of passive relative clauses, which children, similar to adults, produced very often in Study 1. Importantly, passive relatives were found to be infrequent in the child input. These two results show that the high production rate of rare structures, such as passive relatives, is difficult to account for with frequency. We claim that the relation between frequency in natural speech and use of a given variant in a specific context is indirect: speakers may opt for the less grammatically complex computation rather than for the variant most frequently used in spontaneous speech.

Download Full-text

Development of multi-turn reel-to-reel crystallization large furnace for high production rate of YBa2Cu3Oy coated conductors derived from TFA–MOD process

Physica C Superconductivity ◽

10.1016/j.physc.2009.05.025 ◽

2009 ◽

Vol 469 (15-20) ◽

pp. 1336-1340 ◽

Cited By ~ 4

Author(s):

M. Miura ◽

H. Ichikawa ◽

Y. Sutoh ◽

K. Nakaoka ◽

M. Yoshizumi ◽

...

Keyword(s):

Production Rate ◽

Coated Conductors ◽

High Production Rate ◽

High Production ◽

Large Furnace

Download Full-text

The Clipper Field, Blocks 48/19a, 48/19c, UK North Sea

Geological Society London Memoirs ◽

10.1144/gsl.mem.2003.020.01.55 ◽

2003 ◽

Vol 20 (1) ◽

pp. 691-698

Author(s):

M. J. Sarginson

Keyword(s):

North Sea ◽

Upper Permian ◽

Lower Permian ◽

Reservoir Properties ◽

Gas Field ◽

Field Development ◽

Matrix Permeability ◽

Recoverable Reserves ◽

Reservoir Permeability ◽

Sandstone Formation

AbstractThe Clipper Gas Field is a moderate-sized faulted anticlinal trap located in Blocks 48/19a, 48/19c and 48/20a within the Sole Pit area of the southern North Sea Gas Basin. The reservoir is formed by the Lower Permian Leman Sandstone Formation, lying between truncated Westphalian Coal Measures and the Upper Permian evaporitic Zechstein Group which form source and seal respectively. Reservoir permeability is very low, mainly as a result of compaction and diagenesis which accompanied deep burial of the Sole Pit Trough, a sub basin within the main gas basin. The Leman Sandstone Formation is on average about 715 ft thick, laterally heterogeneous and zoned vertically with the best reservoir properties located in the middle of the formation. Porosity is fair with a field average of 11.1%. Matrix permeability, however, is less than one millidarcy on average. Well productivity depends on intersecting open natural fractures or permeable streaks within aeolian dune slipface sandstones. Field development started in 1988. 24 development wells have been drilled to date. Expected recoverable reserves are 753 BCF.

Download Full-text

Experimental Study of DRA for Vertical Two-Phase Annular Flow

Journal of Energy Resources Technology ◽

10.1115/1.3120299 ◽

2009 ◽

Vol 131 (2) ◽

Cited By ~ 7

Author(s):

R. L. J. Fernandes ◽

B. A. Fleck ◽

T. R. Heidrick ◽

L. Torres ◽

M. G. Rodriguez

Keyword(s):

Pressure Gradient ◽

Drag Reduction ◽

Production Rate ◽

Annular Flow ◽

Liquid Holdup ◽

Two Phase ◽

High Production Rate ◽

High Production ◽

Feasibility Test ◽

Main Effects

Experimental investigation of drag reduction in vertical two-phase annular flow is presented. The work is a feasibility test for applying drag reducing additives (DRAs) in high production-rate gas-condensate wells where friction in the production tubing limits the production rate. The DRAs are intended to reduce the overall pressure gradient and thereby increase the production rate. Since such wells typically operate in the annular-entrained flow regime, the gas and liquid velocities were chosen such that the experiments were in a vertical two-phase annular flow. The drag reducers had two main effects on the flow. As expected, they reduced the frictional component of the pressure gradient by up to 74%. However, they also resulted in a significant increase in the liquid holdup by up to 27%. This phenomenon is identified as “DRA-induced flooding.” Since the flow was vertical, the increase in the liquid holdup increased the hydrostatic component of the pressure gradient by up to 25%, offsetting some of reduction in the frictional component of the pressure gradient. The DRA-induced flooding was most pronounced at the lowest gas velocities. However, the results show that in the annular flow the net effect will generally be a reduction in the overall pressure gradient by up to 82%. The findings here help to establish an envelope of operations for the application of multiphase drag reduction in vertical flows and indicate the conditions where a significant net reduction of the pressure gradient may be expected.

Download Full-text