CN113898323B - Marine oil and gas field underwater production system and design method thereof - Google Patents
Marine oil and gas field underwater production system and design method thereof Download PDFInfo
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- 238000013461 design Methods 0.000 title claims abstract description 67
- 238000004519 manufacturing process Methods 0.000 title claims abstract description 40
- 238000000034 method Methods 0.000 title claims abstract description 39
- 239000003921 oil Substances 0.000 claims abstract description 42
- 239000010779 crude oil Substances 0.000 claims abstract description 19
- 238000009826 distribution Methods 0.000 claims abstract description 10
- 239000011159 matrix material Substances 0.000 claims description 82
- 238000005457 optimization Methods 0.000 claims description 25
- 238000010606 normalization Methods 0.000 claims description 12
- 238000003860 storage Methods 0.000 claims description 9
- 238000004364 calculation method Methods 0.000 claims description 7
- 238000013215 result calculation Methods 0.000 claims description 2
- 238000011156 evaluation Methods 0.000 abstract description 5
- 229940112112 capex Drugs 0.000 description 16
- FEBLZLNTKCEFIT-VSXGLTOVSA-N fluocinolone acetonide Chemical compound C1([C@@H](F)C2)=CC(=O)C=C[C@]1(C)[C@]1(F)[C@@H]2[C@@H]2C[C@H]3OC(C)(C)O[C@@]3(C(=O)CO)[C@@]2(C)C[C@@H]1O FEBLZLNTKCEFIT-VSXGLTOVSA-N 0.000 description 16
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 description 15
- 238000011161 development Methods 0.000 description 6
- 238000010586 diagram Methods 0.000 description 5
- 238000009434 installation Methods 0.000 description 2
- 241000191291 Abies alba Species 0.000 description 1
- 241000196324 Embryophyta Species 0.000 description 1
- 241000772415 Neovison vison Species 0.000 description 1
- 238000004422 calculation algorithm Methods 0.000 description 1
- 238000013178 mathematical model Methods 0.000 description 1
- 238000012986 modification Methods 0.000 description 1
- 230000004048 modification Effects 0.000 description 1
- 238000005192 partition Methods 0.000 description 1
- 239000003208 petroleum Substances 0.000 description 1
- 238000012545 processing Methods 0.000 description 1
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- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
- E21B43/01—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells specially adapted for obtaining from underwater installations
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- G—PHYSICS
- G06—COMPUTING; CALCULATING OR COUNTING
- G06F—ELECTRIC DIGITAL DATA PROCESSING
- G06F30/00—Computer-aided design [CAD]
- G06F30/10—Geometric CAD
- G06F30/18—Network design, e.g. design based on topological or interconnect aspects of utility systems, piping, heating ventilation air conditioning [HVAC] or cabling
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- G—PHYSICS
- G06—COMPUTING; CALCULATING OR COUNTING
- G06F—ELECTRIC DIGITAL DATA PROCESSING
- G06F2113/00—Details relating to the application field
- G06F2113/14—Pipes
Abstract
The embodiment of the invention discloses an offshore oil and gas field underwater production system and a design method thereof. The design method of the underwater production system of the offshore oil and gas field comprises the following steps: selecting the number and pipe diameter of the risers according to the obtained crude oil yield of the deepwater oil field; selecting mooring points of the FPSO according to the acquired distribution condition of the underwater wellhead; obtaining a feasible layout point of the FPSO based on the mooring point of the FPSO; performing wellhead grouping on the feasible layout points of the FPSO and the acquired cluster well manifold number to obtain grouping data, and performing layout on the acquired cluster well manifold; obtaining a connection relation between the FPSO and the cluster well manifold based on the grouping data and the distributed cluster well manifold; the FPSO is connected to the cluster well manifold based on the connection of the FPSO to the cluster well manifold and the selected riser. The aims of improving the design evaluation accuracy and the comprehensiveness of the underwater production system of the offshore oil and gas field are achieved.
Description
Technical Field
The invention belongs to the technical field of offshore oil engineering, and particularly relates to an offshore oil and gas field underwater production system and a design method thereof.
Background
Subsea production systems are a central part in the development of deep water fields, which are subsea systems made up of a number of components for production of oil and gas at water depths unsuitable for conventional fixed or sub-sea platform installations. Typically, subsea production facilities primarily include subsea trees, subsea manifolds, pipeline termination manifolds, export pipelines, and subsea connection systems, such as risers, jumpers, connectors, and the like.
In the development of large and medium-sized deep water oil fields with a large number of underwater wellheads, the underwater wellheads are commonly connected to a plurality of cluster well manifolds for joint development so as to produce the whole oil field. The underwater christmas tree installed on the underwater wellhead is connected to each cluster well manifold in turn by the tieback form of jumper-PLET-subsea pipeline-PLET-jumper-cluster well manifold, and then the cluster well manifolds are connected to each other by subsea pipelines for unified transportation to the floating platform. The optimal design of the underwater production system is a critical ring in the design of the deep water oil and gas field development scheme. The optimization design of the underwater production system is divided into the layout of cluster well manifolds and the grouping design of wellheads, and the design of the connection scheme among the cluster well manifolds and PLEM.
At present, some companies and scholars at home and abroad optimize the layout of subsea pipelines and cluster well manifolds of an underwater production system. The Chinese university of Petroleum (Beijing) sequentially provides an optimization method [ Y.Wang, M.Duan, M.Xu, D.Wang, W.Feng, A mathematical model for subsea wells partition in the layout of cluster manifolds, appl. Ocean Res.2012,36:26-35] for optimizing the grouping of underwater wellheads and the layout of cluster wellheads by taking the lowest cost of submarine pipelines as a target and an optimization method [ Y.Wang, M.Duan, J.Feng, D.Mao, M.Xu, S.F.Estefen, modeling for the optimization of layout scenarios of cluster manifolds with pipeline end manifolds, appl. Ocean Res.46 (2014) 94-103 ] for optimizing the connection relation among the cluster wellheads by taking the lowest cost of submarine pipelines as a target in 2012 and 2014 respectively, and the two optimization methods are combined to form a complete set of underwater production system optimization design method. The basic principle of the optimization method is as follows: firstly, continuously changing wellhead grouping and cluster well manifold layout, and selecting a design scheme with the lowest sea pipe cost from a plurality of enumerated schemes as an optimal scheme. Then, continuously changing the connection relation between cluster well manifolds on the basis of the layout design of the cluster well manifolds, and selecting the cluster well manifold connection scheme with the lowest sea pipe cost as an optimal scheme on the basis of ensuring that a closed loop is not formed.
In carrying out the invention, the inventors have found that at least the following problems exist in the prior art
The scheme of the underwater production system at present preferably takes the lowest cost of the submarine pipeline as a preferred target, optimizes the layout of the submarine pipeline, only considers the single target with the lowest cost of the submarine pipeline to be preferred to deviate from the actual engineering, does not consider the safety and the high efficiency of the underwater production system and the cost of the whole underwater production system, and has limitations because the preferred result deviates from the actual engineering to a certain extent.
Disclosure of Invention
In view of the above, the embodiment of the invention provides an offshore oil and gas field underwater production system and a design method thereof, which at least solve the problems that in the prior art, only the single target with the lowest cost of a submarine pipeline is considered, and the single target is preferably deviated from the actual engineering, so that the evaluation result is inaccurate and incomplete.
In a first aspect, an embodiment of the present invention provides a method for designing an offshore oil and gas field underwater production system, including:
selecting the number and pipe diameter of the risers according to the obtained crude oil yield of the deepwater oil field;
selecting mooring points of the FPSO according to the acquired distribution condition of the underwater wellhead;
obtaining a feasible layout point of the FPSO based on the mooring point of the FPSO;
Performing wellhead grouping on the feasible layout points of the FPSO and the acquired cluster well manifold number to obtain grouping data, and performing layout on the acquired cluster well manifold;
obtaining a connection relation between the FPSO and the cluster well manifold based on the grouping data and the distributed cluster well manifold;
the FPSO is connected to the cluster well manifold based on the connection of the FPSO to the cluster well manifold and the selected riser.
In a second aspect, the embodiment of the invention also provides an offshore oil and gas field underwater production system, which is designed by adopting the design method in any one of the first aspects.
According to the method, the number and the pipe diameter of the risers are selected according to the obtained crude oil yield of the deepwater oil field, the mooring points of the FPSO are selected according to the obtained distribution condition of the underwater wellhead, the feasible layout points of the FPSO and the obtained cluster well manifold number are obtained based on the mooring points of the FPSO, wellhead grouping is carried out on the feasible layout points of the FPSO and the obtained cluster well manifold number, grouping data is obtained, the obtained cluster well manifold is laid out, the connection relation between the FPSO and the cluster well manifold is obtained based on the grouping data and the laid cluster well manifold, and in the design, the optimization scheme design and the optimization are carried out on the mooring positions of the FPSO, the pipe diameter and the number of the risers, the pipe diameter of the submarine pipeline, the wellhead grouping, the cluster well manifold layout and the connection relation between the cluster well manifold and the FPSO, so that the design safety and the high efficiency of an offshore oil and gas field underwater production system are improved, and the purposes of improving the design evaluation accuracy and the overall underwater production system of the offshore oil and gas field are achieved.
The method is characterized by comprehensively considering a plurality of underwater equipment such as cluster well manifold, submarine pipelines, jumper pipes, PLET, riser base plates, flexible risers and the like, optimizing scheme design and optimization are carried out on the mooring positions of FPSOs, the pipe diameters and the number of the risers, the pipe diameters of the submarine pipelines, wellhead grouping, cluster well manifold layout and the connection relation between the cluster well manifold and the FPSOs, and multi-objective comprehensive evaluation such as economy, safety, high efficiency and the like is carried out.
Additional features and advantages of the invention will be set forth in the detailed description which follows.
Drawings
The foregoing and other objects, features and advantages of the invention will be apparent from the following more particular descriptions of exemplary embodiments of the invention as illustrated in the accompanying drawings wherein like reference numbers generally represent like parts throughout the exemplary embodiments of the invention.
FIG. 1 illustrates a schematic layout of a subsea production system according to one embodiment of the invention;
FIG. 2 shows a schematic view of a division of a sea floor plan according to an embodiment of the invention;
FIG. 3 illustrates a diagram of all FPSO possible layout points for one embodiment of the invention;
FIG. 4 illustrates a manifold layout and wellhead grouping scheme schematic of one embodiment of the present invention;
FIG. 5 illustrates a manifold-FPSO connection scheme schematic of one embodiment of the invention;
FIG. 6 is a schematic diagram of a subsea production system design with optimum overall performance for one embodiment of the present invention;
figure 7 illustrates a subsea wellhead profile schematic according to one embodiment of the invention.
Detailed Description
Preferred embodiments of the present invention will be described in more detail below. While the preferred embodiments of the present invention are described below, it should be understood that the present invention may be embodied in various forms and should not be limited to the embodiments set forth herein.
FPSO: offshore oil and gas processing plants.
A method of designing an offshore oil and gas field subsea production system comprising:
selecting the number and pipe diameter of the risers according to the obtained crude oil yield of the deepwater oil field;
selecting mooring points of the FPSO according to the acquired distribution condition of the underwater wellhead;
obtaining a feasible layout point of the FPSO based on the mooring point of the FPSO;
performing wellhead grouping on the feasible layout points of the FPSO and the acquired cluster well manifold number to obtain grouping data, and performing layout on the acquired cluster well manifold;
obtaining a connection relation between the FPSO and the cluster well manifold based on the grouping data and the distributed cluster well manifold;
The FPSO is connected to the cluster well manifold based on the connection of the FPSO to the cluster well manifold and the selected riser.
Optionally, the selecting the number and the pipe diameter of the risers according to the obtained crude oil yield of the deepwater oilfield comprises:
determining the maximum engineering pipe diameter and the minimum engineering pipe diameter of the vertical pipe;
determining the maximum number of risers and the minimum number of risers based on the maximum engineering pipe diameter and the minimum engineering pipe diameter;
determining a collocation scheme of the number of the plurality of risers and the pipe diameter based on the determined maximum engineering pipe diameter, minimum engineering pipe diameter, maximum riser number and minimum riser number;
the optimal collocation scheme is selected from the collocation schemes of the number and the pipe diameters of the plurality of risers.
Optionally, the determining a collocation scheme of the number of the plurality of risers and the pipe diameter based on the determined maximum engineering pipe diameter, the determined minimum engineering pipe diameter, the determined maximum riser number and the determined minimum riser number includes:
calculating the optimal pipe diameter corresponding to the number of the risers;
searching engineering actual pipe diameters meeting the optimal pipe diameter requirement in a preconfigured equipment cost library;
calling the unit length cost of the actual pipe diameter of the corresponding engineering;
calculating the number of risers and the related cost of the pipe diameter scheme based on the cost per unit length;
And determining collocation schemes of the number of the risers and the pipe diameter based on the related cost.
Optionally, the determining the maximum riser number and the minimum riser number based on the maximum engineering pipe diameter and the minimum engineering pipe diameter includes:
determining a maximum riser number and a minimum riser number using the following formula;
wherein R is numMAX For maximum riser number, R numMIN For minimum riser number, R dmMAX R is the maximum engineering pipe diameter of the vertical pipe dmMIN Oil is the minimum engineering pipe diameter of the vertical pipe P Is crude oil yield;
and/or
The calculating the optimal pipe diameter corresponding to the number of the risers comprises the following steps:
for the ith number of possible risers, oil P For crude oil production, ++>Is the optimal pipe diameter.
Optionally, the selecting the mooring point of the FPSO according to the acquired distribution situation of the underwater wellhead includes:
determining the boundary of an underwater wellhead;
setting a plurality of point coordinates in a region within the boundary range;
calculating the distance from each point coordinate to each underwater wellhead;
point coordinates that do not meet FPSO berthing requirements are excluded based on the distance.
Optionally, the performing wellhead grouping on the feasible layout points of the FPSO and the acquired cluster well manifold number to obtain grouping data, and performing layout on the acquired cluster well manifold includes:
Determining a number limit for cluster well manifolds;
numbering the number of all the possible manifolds based on the number limit;
performing wellhead grouping, manifold layout and optimization design of a connection scheme on all manifold quantity and FPSO mooring point combination schemes based on the numbered manifold quantity to obtain an optimization design scheme;
determining the maximum value and the minimum value of sea pipe distance, tieback total distance and cluster well manifold in all the optimal design schemes;
respectively calculating fuzzy normalization coefficients of sea pipe distances, total tieback distances and cluster well manifolds in all the optimal design schemes based on the maximum value and the minimum value;
scoring influencing factors in the optimal design scheme to obtain scoring results;
calculating the average value of the scoring result to obtain a judgment matrix;
calculating elements in the judgment matrix to obtain the weight of the influence factor;
determining the maximum value and the minimum value of the influence factors;
calculating fuzzy normalization coefficients of the design scheme influence factors based on the weight, the maximum value and the minimum value, and calculating fuzzy-gray correlation degrees of the schemes;
a preferred design is based on the fuzzy-grey correlation.
Optionally, the optimizing design of wellhead grouping, manifold layout and connection scheme is performed on all manifold numbers and FPSO mooring point combination schemes based on the numbered manifold numbers, and the optimizing design includes:
Randomly arranging cluster well manifolds;
performing wellhead grouping and optimization design of cluster well manifold layout based on result calculation of randomly arranged cluster well manifolds;
calculating the distance from the underwater wellhead of each wellhead subgroup to the corresponding cluster well manifold to obtain a tie-back pipeline of each underwater wellhead, and obtaining the total distance of the tie-back pipelines based on the tie-back pipeline of each underwater wellhead;
renaming the manifold and wellhead subgroups and renaming all feasible FPSO mooring points; to (3) the point;
and optimizing the design of the wellhead group and the manifold and FPSO connection modes of all FPSO feasible mooring points based on the total distance of the tie-back pipelines, the renamed manifold and the renamed FPSO mooring points.
Optionally, the calculating performs optimization design of wellhead grouping and cluster well manifold layout, and includes:
determining the distance between each manifold and the wellhead;
storing the distance between the manifold and the wellhead into a comparison matrix;
storing the underwater wellhead neighborhood into a wellhead team based on the contrast matrix;
renaming underwater wellheads in the wellhead group;
determining the centroid of a wellhead group based on the renamed underwater wellhead;
and judging whether the centroid of each wellhead subgroup is the same as the position of the cluster well manifold.
Optionally, the optimizing design is performed on the wellhead group and the manifold and FPSO connection modes of all the FPSO feasible mooring points based on the total distance of the tie-back pipeline, the renamed manifold and the renamed FPSO mooring points, including:
establishing a manifold and FPSO connection scheme storage matrix;
initializing two matrices for storing endpoints;
connecting cluster well manifolds and FPSOs together in an optimal mode based on the storage matrix and two matrices for storing endpoints to obtain a connection result;
calculating the total length of the submarine pipeline based on the connection result;
determining an optimal theoretical pipe diameter of the subsea pipeline based on the total length of the subsea pipeline;
invoking an optimal engineering pipe diameter conforming to a theoretical optimal pipe diameter and unit length cost in a submarine pipeline cost matrix;
calculating the optimal theoretical pipe diameter of the tie-back pipeline based on the optimal engineering pipe diameter and the unit length cost;
searching the optimal tieback pipeline pipe diameter and unit cost in a submarine pipeline cost matrix based on the optimal theoretical pipe diameter of the tieback pipeline;
evaluating the economic efficiency of optimizing design of a manifold and an FPSO connection mode of all FPSO feasible mooring points based on the pipe diameter of the tie-back pipeline and unit cost;
And evaluating the safety of optimizing design of the manifold and the FPSO connection modes of all the FPSO feasible mooring points based on the pipe diameter of the tie-back pipeline and unit cost.
An offshore oil and gas field underwater production system is designed by adopting the design method.
Embodiment one:
the basic parameter system involved in the method is described in detail as follows:
(1) Expression form of underwater wellhead
Let the underwater wellhead be W 1 ，W 2 ，W 3 ，…，W n Where n is the number of subsea wellheads and its expression also indicates its coordinates. Taking a deepwater oil field as an example, the distribution of underwater wellheads is shown in table 1, whereinSimultaneously, all underwater wellhead coordinates are stored in a matrix W, namely:
TABLE 1 coordinates of underwater wellhead of deep water oilfield (unit: km)
(2) Expression form of cluster well manifold
Let k cluster well manifolds be M 1 ，M 2 ，M 3 ，…，M k The expression also representing its coordinates, i.eLet the maximum and minimum numbers of cluster well manifolds be k respectively MAX ，k MIN 。
(3) Expression form of wellhead group
As shown in FIG. 1, all and manifold M is provided i The underwater wellhead connected by i=1, 2,3, …, k is wellhead subgroup G i I=1, 2,3, …, k, whose subscript k is consistent with the subscript of the cluster well manifold, i.e. whose number is consistent with the cluster well manifold, and whose expression also represents the cluster well manifold M i Connected wellhead coordinate storage matrix, i.e. if cluster well manifold M 1 With underwater wellhead W 1 ，W 2 ，W 3 ，W 4 And (3) connecting:
meanwhile, the number of the underwater wellheads included in the wellhead group is G num 。
(4) Related expression forms of risers
Setting the number of the pipes to be R num Setting the maximum value and the minimum value of the tube number as R respectively numMAX ，R numMIN Setting the pipe diameter of the pipe as R dm (in)。
(5) Expression forms of FPSO
As shown in fig. 1, let FPSO be fpso= (x) FPSO ，y FPSO ) The expression also represents the coordinates of the FPSO anchor.
(6) Expression form of submarine pipeline between manifold and FPSO
The method treats the FPSO as the (k+1) th cluster well manifold when optimizing the connection mode between the cluster well manifold and the FPSO, namelyIf the ith cluster well manifold is connected with the jth cluster well manifold, the length of the submarine pipeline used for connecting the ith cluster well manifold and the jth cluster well manifold is PIPDIS ij (km), let the number of subsea pipelines be PIP num Simultaneously, the pipe diameter of the submarine pipeline connecting the cluster well manifold and the FPSO is PIP dm (in)。
(7) Expression form of tieback pipeline between underwater wellhead and cluster well manifold
If the ith underwater wellhead is connected with the jth cluster well manifold, setting the tieback distance as TBDIS ij (km) with a pipe diameter of TB dm (in)。
(8) Expression form of input parameters
Let the crude Oil yield be Oil p (kbbl/d), let the Water depth be Water D (m) let the development years be P time (year).
(9) Expression form of prefabricated database
Before starting optimization calculation, part of equipment cost database is prefabricated in the form of matrix in algorithm, and submarine pipeline cost matrix is set asEach row of the matrix represents various parameters of a device model, i.eThe cost matrix of the flexible vertical pipe is set asSet the cost matrix of cluster well manifold as
The method comprises the following steps:
the method comprises the following steps of firstly, optimizing the number and pipe diameter of risers according to the crude oil yield of a deepwater oil field:
and 1.1, determining the maximum engineering pipe diameter of the vertical pipe, namely, the maximum pipe diameter of all the vertical pipes available in the engineering. Riser cost matrixAs shown in (1-1), the second column of the matrix represents the pipe diameter of the riser, the maximum value of all elements in the column is the maximum pipe diameter, and is set as R dmMAX (in), in this case R dmMAX ＝12in。
And 1.2, determining the minimum engineering pipe diameter of the stand pipes, namely, the minimum pipe diameter of all stand pipes available in engineering. The minimum value of all elements in the second column of the matrix (1-1) is set as R dmMIN (in), the minimum engineering pipe diameter, R in this case dmMIN ＝8in。
Step 1.3, determining a maximum riser number and a minimum riser number, calculating a maximum number and a minimum number of risers using formula (1-2) (1-3), respectively, wherein And->The upper and lower rounding in the mathematical language are represented respectively, with a maximum riser number of 5 in this case and a minimum riser number of 3. (1-2) (1-3) the following:
R numMAX -maximum riser number, root;
R numMIN -minimum riser number, root;
R dmMAX -maximum engineering pipe diameter of riser, in;
R dmMIN -minimum engineering pipe diameter of the riser, in;
Oil P crude oil production, kbbl/d (kilobarrels per day).
And step 1.4, determining all feasible riser quantity-pipe diameter collocation schemes. Sequentially for all possible riser numbersThe calculations of steps 1.4.1 to 1.4.4 are carried out, in which case the number of possible risers is +.>
And 1.4.1, calculating the optimal pipe diameter corresponding to the number of the risers. Calculating the number of viable risers using (1-4)The corresponding optimal pipe diameter ∈>Namely:
i＝1，2，…，(R numMAX -R numMIN )；
the corresponding optimal pipe diameter, in;
-the ith number of possible risers, root;
Oil P crude oil production, kbbl/d (kilobarrels per day).
R numMAX -maximum riser number, root;
R numMIN -minimum riser number, root;
and 1.4.2, searching the actual engineering pipe diameter meeting the requirement of the optimal pipe diameter in the equipment cost warehouse. Matrix is formedIn (1-1) greater than or equal to and closest to +.>Redefined as +.>I.e.)>The value of the matrix (1-1) is updated to be equal to or greater than +. >Minimum value in the elements of (1), if +.>The initial value of (1-1) is 8.5, all elements in the second column of the comparison matrix find that 10 and 12 meet the above screening conditions, and finally +.>Updated to the minimum of these two elements, i.e. +.>
And 1.4.3, calling the unit length cost of the actual pipe diameter of the corresponding engineering. The updated pipe diameter of the vertical pipeThe corresponding riser unit cost is defined as +.>Order matrix->(1-1)>The first column element of the row is equal to +.>In this case if->Then->
Step 1.4.4, calculate the relevant cost of the riser quantity-pipe diameter scheme. Calculating riser-related costs using (1-5)Riser related costs, i.e. all costs related to riser number, pipe diameter, length, and storing this cost and the corresponding riser number and riser pipe diameter in a matrix (1-6):
riser related costs, USD;
-the ith number of possible risers, root;
the corresponding optimal pipe diameter, in;
corresponding unit cost of the vertical pipe, USD/m;
Water D -water depth, m;
step 1.5, the optimal riser quantity-pipe diameter scheme is preferred. Ending the iteration loop of the steps 1.4.1 to 1.4.4, and adding all RISERs i ，i＝1，2，…，(R numMAX -R numMIN ) Stored to matrix RISER pattern (1-7) costs associated with risersThe smallest riser scheme is taken as a final scheme, and the number, the pipe diameter and the cost of the risers are re-named as R num ，R dm ，RISER COST I.e. the minimum value of the elements of the third column of the matrix (1-7) and the first and second columns of the row, respectively, are equal to the RISER-related cost RISER COST Optimum number of risers R num Optimum pipe diameter R of vertical pipe dm 。
Secondly, optimizing the mooring points of the FPSO according to the distribution condition of the underwater wellhead:
and 2.1, determining the boundary of the underwater wellhead. Finding out the maximum abscissa X of all underwater wellheads MAX Maximum ordinate Y MAX Minimum abscissa X MIN Minimum ordinate Y MIN I.e. the maximum and minimum values of the first and second columns of the matrix W (0-1) are determined by the methods described in step 1.1 and step 1.2, respectively.
And 2.2, setting a plurality of point coordinates in the area within the boundary range. By (X) MIN -3.5，Y MIN -3.5)，(X MIN -3.5，Y MAX +3.5)，(X MAX +3.5，Y MIN -3.5)，(X MAX +3.5，Y MAX +3.5)
Four points are used as endpoints, the submarine plane is divided at intervals of 1km (as shown in figure 2), and all the intersection points are stored in a matrix FPSO base (2-1)。
And 2.3, respectively calculating the distance from each point coordinate to each underwater wellhead. Matrix FPSO base The point in (2-1) is FPSO i I=1, 2, …,3016, each FPSO is calculated separately i And each underwater wellhead W in matrix W (0-1) j Distance L of j=1, 2, …,20 ij The method comprises the following steps:
L ij -ith intersection point FPSO i With the j-th underwater wellhead W j Distance, km;
intersection FPSO i Is the abscissa, km;
intersection FPSO i Is the ordinate of km;
-subsea wellhead W j Is the abscissa, km;
-subsea wellhead W j Is the ordinate of km.
And 2.4, excluding point coordinates which do not meet the mooring requirements of the FPSO. If a certain FPSO i And each underwater wellhead W j Distance L of j=1, 2, …,20 ij J=1, 2, …,20 are all 3.5km or more, the point is reserved, otherwise in matrix FPSO base Deleting the point in (2-1), and obtaining all the points which are the feasible layout points of the FPSO (as shown in figure 3).
And thirdly, sequentially carrying out wellhead grouping, cluster well manifold layout and optimization of FPSO-cluster well manifold connection relations on all the feasible layout points of the FPSOs and the number of cluster well manifolds. This step may be accomplished by the following detailed steps:
and 3.1, determining the number limit of cluster well manifolds. Since the maximum number of slots and the minimum number of slots of the cluster well manifold are 14 and 4, respectively, the maximum number k of cluster well manifolds is calculated by using the formulas (3-1) and (3-2), respectively MAX And a minimum number k MIN WhereinAnd->Respectively represent upper rounding and lower rounding in mathematical language, taking the deepwater oil fields of the 20 underwater wellheads as examples, the maximum number k of cluster well manifolds MAX =5 minimum number k MIN =2, formula (3-1) and formula (3-2) are as follows:
k MAX -maximum number of cluster well manifolds, individual;
k MIN -a minimum number of cluster well manifolds, one;
n-number of subsea wellheads.
Step 3.2, numbering all possible manifold numbers, defining all possible manifold numbers as k i ，i＝1，2，…，(k MAX -k MIN +1), if k MAX ＝5，k MIN Let =2 then k 1 ，k 2 ，…，k 4 ＝2，3，4，5。
Step 3.3, performing wellhead grouping and manifold layout on all manifold quantity-FPSO mooring point combination schemesAnd an optimized design of the connection scheme. In turn for all feasible cluster well manifold numbers k i I=1, 2, …,4 the following calculations of steps 3.3.1 to 3.3.6 were performed;
step 3.3.1, randomly arranging cluster well manifolds. Let k=k i (1, 2, …, 4), k cluster well manifolds M are randomly selected j J=1, 2,3, … k is arranged in the subsea production system.
And 3.3.2, performing wellhead grouping and optimization design of cluster well manifold layout by using the calculation of the steps 3.3.2.1 to 3.3.2.7.
In step 3.3.2.1, the distance between each manifold and the wellhead is determined. Each underwater wellhead W is calculated by using the method (3-3) i I=1, 2,3, …, n and each cluster well manifold M j Distance TBDIS between j=1, 2,3, …, k ij The method comprises the following steps:
i＝1，2，…，n，j＝1，2，…，k；
TBDIS ij -ith subsea wellhead W i And j-th cluster well manifold M j Distance, km;
underwater wellhead W i Is the abscissa, km;
underwater wellhead W i Is the ordinate of km;
cluster well manifold M j Is the abscissa, km;
cluster well manifold M j Is the ordinate of km;
in step 3.3.2.2, the distance between the manifold and the wellhead is stored in a comparison matrix. Will be under water the well head W i And each cluster well manifold M 1 ，M 2 ，…，M k Is a distance TBDIS of (C) ij I=1, 2, …, n, j=1, 2, …, k is stored in the contrast matrix TBDIS compare (3-4) the ith row of the matrix represents the ith subsea wellhead W i Distance from k cluster well manifolds, namely:
and step 3.3.2.3, storing the underwater wellhead nearby into a wellhead group. Sequentially distributing n underwater wellheads to wellhead subgroups where cluster well manifolds closest to the n underwater wellheads are located, and if a matrix TBDIS is formed compare (3-4) TBDIS in line 1 12 Minimum, the 1 st underwater wellhead W 1 Storing in group 2, i.e. matrix G 2 (3-5)：
Underwater wellhead W 1 Is the abscissa, km;
underwater wellhead W 1 Is the ordinate of km.
Step 3.3.2.4 renaming the underwater wellhead in the wellhead group. Setting the ith wellhead subgroup, i.e. matrix G i The number of lines of i=1, 2, …, k isWhile re-aligning each wellhead teamNumbering underwater wellhead in (C), if wellhead subgroup G 1 The 4 underwater wellheads are stored in the well, and then the 4 underwater wellheads are respectively renamed as W 11 ，W 12 ，W 13 ，W 14 As shown in formulas (3-6), this nomenclature changes only the wellhead subgroup, matrix G i I=1, 2, …, k, without changing the original subsea wellhead name, i.e. W 1 ，W 2 ，…，W n The number of (2) is unchanged.
In step 3.3.2.5, the centroid of the wellhead team is determined. Calculating the centroids of the underwater wellheads in each wellhead subgroup respectively by using (3-7), and naming the centroid of the ith wellhead subgroup as newM i I=1, 2, …, k, formula (3-7) is as follows:
-ith wellhead group G i The number of the well heads in the well;
—newM i is the abscissa, km;
—newM i is the ordinate of km;
-ith wellhead group G i Middle jth underwater wellhead W ij Is the abscissa, km;
-ith wellhead group G i Middle jth underwater wellhead W ij Is the ordinate of km.
In step 3.3.2.6, it is determined whether the centroid of each wellhead subgroup is the same as the cluster well manifold. Sequentially calculating an ith wellhead subgroup G using (3-8) i Cluster well manifold M in (a) i newM with its centroid i Distance betweenIf->Not 0 but M i ＝newM i On the contrary M i Unchanged, the formula (3-8) is as follows:
i＝1，2，…，k；
-abscissa, km, of the ith cluster well manifold;
-ordinate, km of the ith cluster well manifold;
-ith well head subgroup centroid newM i Is the abscissa, km;
-ith well head subgroup centroid newM i Is the ordinate of km;
step 3.3.2.7, it is determined whether to stop the iteration. Repeating steps 3.3.2.1-3.3.2.6, if the step 3.10 is calculatedAll 0, the iteration loop is stopped.
And 3.3.3, calculating the total distance of the tie-back pipeline. Respectively calculating the distance from the underwater wellhead of each wellhead group to the corresponding cluster well manifold by using the method (3-9)Calculating the total wellhead tie-back distance TBDIS by using the method (3-10) total The formula (3-9) (3-10) is as follows:
-ith wellhead group G i The number of the well heads in the well;
TBDIS ij -the distance between the ith cluster well manifold and the jth underwater wellhead connected thereto, km;
-ith cluster well manifold M i Is the abscissa, km;
-ith cluster well manifold M i Is the ordinate of km;
-ith wellhead group G i Middle jth underwater wellhead W ij Is the abscissa, km;
-ith wellhead group G i Middle jth underwater wellhead W ij Is the ordinate of km;
step 3.3.4 renaming the manifold and wellhead team. The cluster well manifold layout coordinate obtained by calculation in the steps is re-named as M in wellhead grouping scheme ki I=1, 2, …, k and G ki I=1, 2, …, k, where the subscript k indicates the number of cluster well manifolds of the scheme, i indicates the number of the cluster well manifold or wellhead subgroup, i.e., the i-th cluster well manifold or wellhead subgroup in the scheme, and the optimization results are shown in fig. 4 taking 5-manifold as an example.
Step 3.3.5 renaming all possible FPSO anchor points. Matrix FPSO base Each row of elements in (2-1) is defined asWherein->And->Respectively represent matrix FPSO base The elements of row 1 and column 2 of i, i.e., the i-th FPSO.
Step 3.3.6, optimizing the manifold-FPSO connection mode of all FPSO feasible mooring points, and carrying out economy and safety evaluation. Feasible mooring points for all FPSOs in turnThe following calculations from step 3.3.6.1 to step 3.3.6.11 are performed.
Step 3.3.6.1, establishing a manifold-FPSO Connection scheme storage matrix Connection pattern (3-11). If there are 3 cluster well manifolds M 1 ，M 2 ，M 3 Wherein M is 1 And M is as follows 2 Connected to, M 2 Connected to FPSO, M 3 Connected to FPSO, matrix Connection pattern (3-11) wherein the two digits on each column are the subscripts of a pair of interconnected cluster well manifolds, 0 representing the FPSO.
In step 3.3.6.2, two matrices V (3-12) and U (3-13) for the storage endpoint are initialized. Order theAnd store it in matrix V (3-12), the rest of cluster well manifolds are stored in matrix U (3-13):
V＝[x FPSO y FPSO ] (3-12)
x FPSO -abscissa of FPSO mooring points, km;
y FPSO -the ordinate of the FPSO mooring point, km;
-abscissa, km, of cluster well manifold No. 1;
-ordinate, km of cluster well manifold number 1;
Step 3.3.6.3, using steps 3.3.6.3.1-3.3.6.3.4, the cluster well manifold and FPSO are optimally coupled together.
In step 3.3.6.3.1, the distances between all points in the two matrices V and U are calculated. Let i-th behavior in matrix V (3-12)Let j's act in matrix U (3-13)>And all V are calculated by using (3-14) i And all U' s j Distance of->I.e. the distances between all points in the matrix V and all points in the matrix U are calculated pairwise:
-the distance km between the element of row i in matrix V and the element of row j in matrix U;
—V i is the abscissa, km;
—V i is the ordinate of km;
—U j is the abscissa, km;
—U j is the ordinate of km;
in step 3.3.6.3.2, the two points with the smallest distance are selected and the matrices U and V are adjusted. All L are compareij U corresponding to the minimum value of (3) j Is stored in matrix V and renamed by the naming method in step 3.3.6.3.1, if there are 3 cluster well manifolds and manifold M in the subsea production system 1 The minimum distance from the FPSO anchor point, the above method can be described by the formula (3-15) (3-16):
/>
in step 3.3.6.3.3, the connection scheme storage matrix is updated. Using the method of step 3.3.6.1 to convert M 1 The Connection relation between the FPSO and the manifold-FPSO is stored in a manifold-FPSO Connection scheme storage matrix Connection pattern In (1) and simultaneously distance between themStored in the third row of the matrix, the collective method is as in formulas (3-17):
in step 3.3.6.3.4, it is determined whether the iteration has stopped. If all cluster well manifolds in the matrix U are stored in the matrix V, that is, if the matrix u=0, the iteration is stopped, otherwise, the iteration is continued to be operated, and taking 5 manifolds as an example, the connection scheme after the iteration is finished is shown in fig. 5.
Step 3.3.6.4, calculate the total length of the subsea pipeline. If the matrix Connection is obtained through several iterations pattern The column number is a, the matrix is thenThe third column element, i.e., the length between the two points, is renamed Li, i=1, 2, …, a, and the matrix Connection is calculated using equation (3-18) pattern The sum of the third row elements, i.e. the total length of sea pipe PIPDIS connecting the FPSO and cluster well manifold total The formula (3-18) is as follows:
PIPDIS total -total distance of subsea pipelines connecting the FPSO and cluster well manifold, km;
L i -the length of the ith subsea pipeline, km;
a-number of subsea pipelines, root.
Step 3.3.6.5, determining the optimal theoretical pipe diameter of the submarine pipeline. Oil production according to the crude Oil production by the formula (3-19) P Calculating the optimum theoretical pipe diameter PIP of submarine pipeline dmt ：
PIP dmt -optimal theoretical pipe diameter, in, of subsea pipeline;
Oil P crude oil yield, kbbl/d.
Step 3.3.6.6, matrix of costs on subsea pipeline And calling the optimal engineering pipe diameter conforming to the theoretical optimal pipe diameter and the unit length cost. Known subsea pipeline cost matrix->Column 1 represents pipeline unit cost, column 2 represents pipe diameter, column 3 represents applicable water depth, and matrix +.>All columns 2 of (a) are greater than or equal to PIP dmt And column 3 is greater than or equal to Water depth Water D Row entry matrix->Matrix->The minimum value in column 1 element is defined as PIP price The column 2 element of the row is defined as PIP dm 。
Step 3.3.6.7, calculating the optimal theoretical pipe diameter TB of the tie-back pipeline by using the formula (3-20) dmt ：
TB dmt -optimal theoretical pipe diameter of tie-back line, in;
Oil P -crude oil yield, kbbl/d;
n-number of underwater wellheads, ports.
Step 3.3.6.8, using the same method as step 3.3.6.6, on subsea pipeline cost matrixMiddle search optimal tieback pipeline pipe diameter TB dm Unit cost TB price 。
Step 3.3.6.9, the design is evaluated for economy. Calculating the cost of each device or system in the underwater production system by using the formulas (3-21) to (3-36), and finally calculating the overall cost CAPEX of the design scheme, namely the scheme economy:
C 1 ＝CAPEX Xtree ＝n×10000000 (3-21)
C 2 ＝CAPEX manifold ＝k×5000000 (3-22)
C 3 ＝CAPEX PIPconnectors ＝(n+2k)×1680000 (3-23)
C 4 ＝CAPEX UBconnectors ＝n×124000+k×882000 (3-24)
C 5 ＝CAPEX guidebase ＝n×400000 (3-25)
C 6 ＝CAPEX TB ＝TBDIS total ×TB price +n×128000 (3-26)
C 7 ＝CAPEX leads ＝(n+3k)×519000 (3-27)
C 8 ＝CAPEX control ＝n×1778500+10532000 (3-28)
C 9 ＝CAPEX PIP ＝2×PIPDIS total ×PIP price (3-29)
C 10 ＝CAPEX PLETS ＝(2k+n)×5824000 (3-30)
C 11 ＝CAPEX UB ＝(PIPDIS total +TBDIS total )×819200 (3-31)
C 12 ＝CAPEX RISER ＝RISER COST (3-32)
n-number of underwater wellheads, ports;
k-number of cluster well manifolds, stands;
TBDIS total -tieback total length, km;
TB price -tie-back line cost per unit length, USD/km;
PIPDIS total -total subsea pipeline length km;
PIP price -subsea pipeline unit length cost, USD/km;
RISER COST riser related costs, USD;
C 1 -subsea tree overall cost, USD;
C 2 -cluster well manifold overall cost, USD;
C 3 -the overall cost of the subsea connector, USD;
C 4 -umbilical connector overall cost, USD;
C 5 -overall cost of subsea wellhead, USD;
C 6 -wellhead tie-back overall cost, USD;
C 7 -flying lead connector overall cost, USD;
C 8 -overall cost of the subsea control system, USD;
C 9 -subsea pipeline overall cost, USD;
C 10 -complete cost of the PLETs, USD;
C 11 -umbilical overall cost, USD;
C 12 -flexible riser overall cost, USD;
C 13 transportation cost, USD;
C 14 installation cost, USD;
C 15 -other costs, USD;
capex—overall cost of subsea production system, USD.
Step 3.3.6.10, calculate security SAFE for the scheme SAFE using formula (3-37):
SAFE-security factor;
t-development years, years;
PIPDIS total -total subsea pipeline length km;
TBDIS total -tieback total length, km;
in step 3.3.6.11, the optimization design data is integrated into the correlation matrix. Mooring position fpso= (x) FPSO ，y FPSO ) Cluster well manifold number k, tieback total length TBDIS total Pipe diameter TB of tie-back pipeline dm Total submarine pipeline length PIPDIS total Pipe diameter PIP of submarine pipeline dm The overall cost of the underwater production system CAPEX and the safety factor SAFE are stored in the matrix patterm, and table 2 shows the top five economic ranking scheme data, with the transpose (rank interchange) shown in table 2, since more elements of each row in the matrix patterm cannot be shown in the file.
TABLE 2 transposed mode of matrix PATTERN after iteration is complete
And 3.4, determining the maximum value and the minimum value of the sea pipe distance, the tieback total distance and the cluster well manifold in all the optimal design schemes. After all iterations are completed, compare all sea pipe distances PIPDIS in matrix PATTER total Total tieback distance TBDIS total And manifold number k, the maximum sea pipe distance is named maxPIDIS total The minimum sea pipe distance is named minPIPDIS total The maximum tieback total distance is named maxTBDIS total The minimum tieback total distance is named minTBDIS total The maximum manifold number is named maxk and the minimum manifold number is named mink.
And 3.5, respectively calculating fuzzy normalization coefficients of sea pipe distances, total tieback distances and cluster well manifolds in all the optimal design schemes. The high efficiency EFF of each row (i.e. each set of design scheme) in the matrix PATTER is calculated in sequence by using the formulas (3-38) to (3-41), and is stored in the matrix PATTER by using the mode of step 3.3.6.11, wherein the formulas (3-38) to (3-41) are as follows:
PIPDIS total ' fuzzy normalization coefficient of sea pipe total length;
TBDIS total ' -tie-back fuzzy normalization coefficients of the total distance;
k' -fuzzy normalization coefficient of manifold number;
EFF-coefficient of efficiency;
maxPIPDIS total -maximum sea pipe distance, km;
minPIPDIS total -minimum sea pipe distance, km;
PIPDIS total -sea pipe distance, km;
maxTBDIS total -maximum tieback distance, km;
minTBDIS total -minimum tieback distance, km;
TBDIS total -tieback distance, km;
maxk—maximum manifold number;
mink—minimum manifold number;
k-manifold number.
Step 3.6, let the economy be influence factor 1, the safety be influence factor 2, the high efficiency be influence factor 3, please 10 underwater production system experts score three influence factors by using 1-9 grades and reciprocal scale method thereof, and the 1-9 grades scale is shown in table 3:
tables 3 1-9 scale schematic
Step 3.7, calculating the average value of 10 expert scores to obtain a judgment matrix Q (3-42):
step 3.8, calculating the elements in the judgment matrix Q by using the formula (3-43) to obtain weights Q of three influencing factors 1 ，Q 2 ，Q 3 ：
Q i -the weight of the ith influencing factor;
q ij -a judging element of importance of the ith influencing factor with respect to the jth influencing factor;
and 3.9, determining the maximum value and the minimum value of the economical coefficient, the safety coefficient and the high efficiency coefficient. Using the method in the step 3.4 to respectively name the maximum and minimum values of CAPEX in the matrix PATTER as maxCAPEX and minCAPEX, respectively name the maximum and minimum values of the security coefficient SAFE as maxSAFE and minSAFE, respectively name the maximum and minimum values of the high-efficiency coefficient EFF as maxEFF and minEFF;
And 3.10, calculating fuzzy normalization coefficients of economy, safety and high efficiency of each design scheme, and calculating fuzzy-gray correlation degree of each scheme. The fuzzy-gray correlation of each set of design schemes (i.e., each row of data of matrix PATTERN) is calculated in turn using equations (3-44) through (3-47) and stored into matrix PATTERN using step 3.3.6.11, equations (3-44) through (3-47) are as follows:
CAPEX' -fuzzy normalization coefficient of scheme economy;
SAFE' -fuzzy normalization coefficients of scheme security;
EFF' -fuzzy normalization coefficient of scheme efficiency;
AP-fuzzy-gray correlation;
maxcapex—maximum investment cost, USD;
minCAPEX-minimum investment cost, USD;
CAPEX-investment cost, USD;
maxsafe—security coefficient maximum;
minsafe—security coefficient minimum;
SAFE-security factor;
maxeff—high efficiency coefficient maximum;
minEFF—minimum coefficient of efficiency;
EFF-coefficient of efficiency;
Q 1 ，Q 2 ，Q 3 -weights of influencing factor 1, influencing factor 2, influencing factor 3.
Step 3.11, after all iterations are completed, comparing all schemes in the matrix patterm, wherein the scheme with the highest fuzzy-gray correlation degree is the scheme with the best comprehensiveness, wherein table 4 shows scheme data of the fifth scheme with the highest fuzzy-gray correlation degree, and fig. 6 shows a schematic diagram of the scheme with the highest fuzzy-gray correlation degree.
Table 4 top 5 scheme data
Embodiment two:
taking a deepwater oil field as an example, carrying out the optimal design of an underwater production system, wherein the deepwater oil field has a water depth of 2200m, 20 underwater wellheads and a daily yield of 20 ten thousand barrels (200 kbbl/d), the detailed coordinates of the underwater wellheads are shown in a table 5, and the distribution diagram of the underwater wellheads is shown in fig. 7:
TABLE 5 coordinates of underwater wellhead of deep water oilfield (unit: km)
Firstly, optimizing the pipe diameter and the number of the risers according to the daily yield of crude oil of the deepwater oil field, and obtaining 3 risers with 12in an optimal riser combination scheme.
All possible FPSO mooring points are then determined (as shown in fig. 3).
Finally, the wellhead grouping, cluster well manifold layout and FPSO-manifold connection mode are optimally designed, finally, the optimal design scheme is optimized, scheme data of the first five ranks are shown in a table 6, and a scheme schematic diagram with the highest fuzzy-gray correlation degree is shown in fig. 5.
Table 6 top 5 scheme data
The foregoing description of embodiments of the invention has been presented for purposes of illustration and description, and is not intended to be exhaustive or limited to the embodiments disclosed. Many modifications and variations will be apparent to those of ordinary skill in the art without departing from the scope and spirit of the various embodiments described.
Claims (2)
1. A method of designing an offshore oil and gas field subsea production system, comprising:
selecting the number and pipe diameter of the risers according to the obtained crude oil yield of the deepwater oil field;
selecting mooring points of the FPSO according to the acquired distribution condition of the underwater wellhead;
obtaining a feasible layout point of the FPSO based on the mooring point of the FPSO;
performing wellhead grouping on the feasible layout points of the FPSO and the acquired cluster well manifold number to obtain grouping data, and performing layout on the acquired cluster well manifold;
obtaining a connection relation between the FPSO and the cluster well manifold based on the grouping data and the distributed cluster well manifold;
connecting the FPSO with the cluster well manifold based on the connection of the FPSO with the cluster well manifold and the selected riser;
wherein, the quantity and pipe diameter of the riser are selected according to the obtained crude oil yield of the deepwater oil field, and the method comprises the following steps:
determining the maximum engineering pipe diameter and the minimum engineering pipe diameter of the vertical pipe;
determining the maximum number of risers and the minimum number of risers based on the maximum engineering pipe diameter and the minimum engineering pipe diameter;
determining a collocation scheme of the number of the plurality of risers and the pipe diameter based on the determined maximum engineering pipe diameter, minimum engineering pipe diameter, maximum riser number and minimum riser number;
Selecting a preferable collocation scheme from the collocation schemes of the number and the pipe diameters of the plurality of risers;
the collocation scheme for determining the number of the plurality of risers and the pipe diameter based on the determined maximum engineering pipe diameter, the determined minimum engineering pipe diameter, the determined maximum riser number and the determined minimum riser number comprises the following steps:
calculating the optimal pipe diameter corresponding to the number of the risers;
searching engineering actual pipe diameters meeting the optimal pipe diameter requirement in a preconfigured equipment cost library;
calling the unit length cost of the actual pipe diameter of the corresponding engineering;
calculating the number of risers and the related cost of the pipe diameter scheme based on the cost per unit length;
determining collocation schemes of the number of the risers and the pipe diameter based on the related cost;
wherein the determining the maximum riser quantity and the minimum riser quantity based on the maximum and minimum engineering pipe diameters comprises:
determining a maximum riser number and a minimum riser number using the following formula;
wherein R is numMAX For maximum riser number, R numMIN For minimum riser number, R dmMAX R is the maximum engineering pipe diameter of the vertical pipe dmMIN Oil is the minimum engineering pipe diameter of the vertical pipe p Is crude oil yield;
the calculating the optimal pipe diameter corresponding to the number of the risers comprises the following steps:
for the ith number of possible risers, oil P For crude oil production, ++ >Is the optimal pipe diameter;
wherein, according to the distribution condition of the underwater wellhead that obtains, select the mooring point of FPSO, include:
determining the boundary of an underwater wellhead;
setting a plurality of point coordinates in a region within the boundary range;
calculating the distance from each point coordinate to each underwater wellhead;
excluding point coordinates that do not meet FPSO berthing requirements based on the distance;
the method for performing wellhead grouping on the feasible layout points of the FPSO and the acquired cluster well manifold number to obtain grouping data, and performing layout on the acquired cluster well manifold comprises the following steps:
determining a number limit for cluster well manifolds;
numbering the number of all the possible manifolds based on the number limit;
performing wellhead grouping, manifold layout and optimization design of a connection scheme on all manifold quantity and FPSO mooring point combination schemes based on the numbered manifold quantity to obtain an optimization design scheme;
determining the maximum value and the minimum value of sea pipe distance, tieback total distance and cluster well manifold in all the optimal design schemes;
respectively calculating fuzzy normalization coefficients of sea pipe distances, total tieback distances and cluster well manifolds in all the optimal design schemes based on the maximum value and the minimum value;
Scoring influencing factors in the optimal design scheme to obtain scoring results;
calculating the average value of the scoring result to obtain a judgment matrix;
calculating elements in the judgment matrix to obtain the weight of the influence factor;
determining the maximum value and the minimum value of the influence factors;
calculating fuzzy normalization coefficients of the design scheme influence factors based on the weight, the maximum value and the minimum value, and calculating fuzzy-gray correlation degrees of the schemes;
obtaining a preferred design scheme based on the fuzzy-gray correlation;
the optimized design of wellhead grouping, manifold layout and connection scheme is carried out on all manifold quantity and FPSO mooring point combination schemes based on the numbered manifold quantity, and the optimized design comprises the following steps:
randomly arranging cluster well manifolds;
performing wellhead grouping and optimization design of cluster well manifold layout based on result calculation of randomly arranged cluster well manifolds;
calculating the distance from the underwater wellhead of each wellhead subgroup to the corresponding cluster well manifold to obtain a tie-back pipeline of each underwater wellhead, and obtaining the total distance of the tie-back pipelines based on the tie-back pipeline of each underwater wellhead;
renaming the manifold and wellhead subgroups and renaming all feasible FPSO mooring points; to (3) the point;
Optimizing the design of a wellhead group and manifold and FPSO connection modes of all FPSO feasible mooring points based on the total distance of the tie-back pipelines, the renamed manifold and the renamed FPSO mooring points;
the calculation is used for carrying out optimization design of wellhead grouping and cluster well manifold layout, and the method comprises the following steps:
determining the distance between each manifold and the wellhead;
storing the distance between the manifold and the wellhead into a comparison matrix;
storing the underwater wellhead neighborhood into a wellhead team based on the contrast matrix;
renaming underwater wellheads in the wellhead group;
determining the centroid of a wellhead group based on the renamed underwater wellhead;
judging whether the centroid of each wellhead subgroup is the same as the position of the cluster well manifold;
the optimization design is carried out on the wellhead group and manifold and FPSO connection modes of all FPSO feasible mooring points based on the total distance of the tie-back pipelines, the renamed manifold and the renamed FPSO mooring points, and the optimization design comprises the following steps:
establishing a manifold and FPSO connection scheme storage matrix;
initializing two matrices for storing endpoints;
connecting cluster well manifolds and FPSOs together in an optimal mode based on the storage matrix and two matrices for storing endpoints to obtain a connection result;
Calculating the total length of the submarine pipeline based on the connection result;
determining an optimal theoretical pipe diameter of the subsea pipeline based on the total length of the subsea pipeline;
invoking an optimal engineering pipe diameter conforming to a theoretical optimal pipe diameter and unit length cost in a submarine pipeline cost matrix;
calculating the optimal theoretical pipe diameter of the tie-back pipeline based on the optimal engineering pipe diameter and the unit length cost;
searching the optimal tieback pipeline pipe diameter and unit cost in a submarine pipeline cost matrix based on the optimal theoretical pipe diameter of the tieback pipeline;
evaluating the economic efficiency of optimizing design of a manifold and an FPSO connection mode of all FPSO feasible mooring points based on the pipe diameter of the tie-back pipeline and unit cost;
and evaluating the safety of optimizing design of the manifold and the FPSO connection modes of all the FPSO feasible mooring points based on the pipe diameter of the tie-back pipeline and unit cost.
2. An offshore oil and gas field subsea production system, characterized in that it is designed by the design method according to claim 1.
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