The invention relates to a tight oil flow simulation and permeability prediction method based on a pore network model. The method includes the following steps: (1) scanning a tight core to obtain a two-dimensional electron microscope image and obtain spatial geometric information of porous medium pores; (2) reconstructing a digital core to obtain a geometric data file of the digital core; (3) extracting the pore network model of the digital core to obtain a data file of the pore network model of the tight core; (4) obtaining the pressure at each pore and the volume flow rate at each pore throat position to further obtain the flowing condition of a fluid in the nano-scale pore network model; (5) obtaining the volume flow rate Q of the fluid at the outlet end of the pore network model and calculating the apparent permeability of the pore network model according to the Darcy law. The newly developed pore network model overcomes the shortcoming that the traditional pore network model cannot consider the boundary slip and the change of the effective viscosity of the fluid when the fluid flows in the nanopores.

Tight oil flow simulation and permeability prediction method based on pore network model

The invention belongs to the technical field of scientific research of oil and provides a method for measuring capillary pressure of a CO2-saline-core system based on an X-ray CT technology. The measuring method disclosed by the invention comprises the following four steps: measuring CO2-saline interfacial tension, performing core displacement and CT scanning, performing CT image processing and measuring the capillary pressure. By utilizing the X-ray CT technology, the method disclosed by the invention has the characteristics of relatively high resolution and capacity of performing nondestructive testing on samples, is capable of accurately, conveniently and really measuring the capillary pressure of the CO2-saline-core system in different flow conditions, and can measure local core capillary pressure and overall core capillary pressure, so that the measurement scale reaches the pore scale. Moreover, the measuring method can be popularized to measuring the capillary pressure of any gas-liquid porous medium system or liquid-liquid porous medium system.

Method for measuring capillary pressure of CO2-saline-core system based on X-ray computed tomography (CT) technology

The invention provides a method for predicting the permeability of coal under stress loading conditions based on CT scans, and solves the technical problem of calculating the permeability of deformedcoal. The method comprises the following steps: A, Making a coal sample, conducting a uniaxial compression experiment, and performing CT scans on the coal sample; B, performing threshold segmentationby adopting a digital terrain model method to obtain a threshold value of the coal sample, and importing CT scan images into a modeling software to establish a three-dimensional numerical model; C, importing the three-dimensional numerical model into a finite element analysis software and setting seepage conditions; D, applying a plurality of pressure gradient values nabla P to the three-dimensional numerical model, setting an initial flow velocity v0, adjusting the nabla P and the v0 parameters to obtain a plurality of seepage models; E, importing the seepage model into a finite element software for simulation and calculation to obtain a calculation result; And F, importing the calculation result into a data processing software, extracting the seepage velocity at equal intervals along theseepage direction, obtaining the relationship between the seepage velocity and the pressure gradient, and calculating the permeability.

Method for predicting permeability of coal under stress loading conditions based on CT scans

(12) i N j 9(- WJP? I IN -Ef |EP $ l (10)9)) () Pd'VT WO 2020/015086 A1 2020 4T1f - P23 (23.01.2020) WIPO I PCT (51) ) pj9 4T1 }% : (72) & )A: J1id(LIU, Jiangfeng); +P4I G06T 7/00 (2017.01) 1 r1 ]T i Li Y 1 Jiangsu 221116 (CN)o (21) ) PCT/CN2018/104640 Illt t(CAO, Xulou); + T )413 r I Ni Li Ex * 1 I Jiangsu 221116 (CN)0 o I, Yh (22) M pj: $igH : 2018 9 19 7 H (07.09.2018) (CHEN, Shijie); F Pr Li E (25)$ : F §1 M , Jiangsu 221116 (CN)o W M (HUANG, Bingxiang); FP4 i H iTM LfX1, (26) zf i : F Jiangsu 221116 (CN)0 o Afi t (CHEN, Zherui); (30) I fR: + 4l I i & lf i ,X tMI Jiangsu 201810788898.1 2018 4 7A]18H (18.07.2018) CN 221116 (CN) &)tJ-(SONG, Shuaibing); +[ (71) $ifA : *- M r Lt (C (CHINA UNIVERSITY 4 IT NN r ,I Jiangsu 221116 OF MINING AND TECHNOLOGY) [CN/CN]; ± (CN) o 58I f(NI,Hongyang); F lll 41l 3 )H1 r4 L [ fit 1 , Jiangsu rNH W #Ex 1 , Jiangsu 221116 (CN)o 221116 (CN)o 4 ')11 Mi * r (74) (*I4 :j h P1J /, $(74)N F 15 (XUZHOU USURE MINING TECHNOLOGY CO., 1) (NANJING JINGWEI PATENT & TRADEMARK LTD) [CN/CN]; + T )H1 AGENCYCO.,LTD); + ilT M$riP X 99 -$ u *r X \J W{ A X i 710, WY179912 B) , Jiangsu210005 (CN)o Jiangsu221116 (CN)o (54) Title: POROUS MEDIUM PERMEABILITY PREDICTION METHOD BASED ON INTELLIGENT MACHINE IMAGE cc SEMf-MR AA BB AA SEM scanner BB Computer CC Result output display device (57) Abstract: Disclosed is a porous medium permeability prediction methodbased on intelligent machine image learning. The method comprises: selecting multiple groups of porous medium materials of the same type but different dry densities, and determining the real permeability of each group of porous medium materials; scanning each group of porous medium materials using an SEM to obtain SEM images thereof, and then calculating a gray average, a gray variance, an image energy, an image entropy and a fractal dimension of each of the SEM images; using an extreme learning machine neural network model to perform training and learning on five image I feature parameters of each of the SEM images and the real permeability corresponding thereto to determine a change relationship between the five image feature parameters and the real permeability; and during prediction, inputting parameters of the SEM image of a porous medium material of unknown permeability, the extreme learning machine neural network model being able to predict thereby the permeability of the porous medium material. The present invention is simple to operate and has a short test period, achieves a high Accuracy of predicted permeability and is low in test costs. W O 2020/015086 A 1 |||||111I||I|I||I|||||I|||||I|I|I|I|111|||IIII |||||||||||||||||||||||||||| (81) 1 M5 (4jI M hR HA, n- tf Ef)f) : AE, AG, AL, AM, AO, AT, AU, AZ, BA, BB, BG, BH, BN, BR, BW, BY, BZ, CA, CH, CL, CN, CO, CR, CU, CZ, DE, DJ, DK, DM, DO, DZ, EC, EE, EG, ES, Fl, GB, GD, GE, GH, GM, GT, HN, HR, HU, ID, IL, IN, IR, IS, JO, JP, KE, KG, KH, KN, KP, KR, KW, KZ, LA, LC, LK, LR, LS, LU, LY, MA, MD, ME, MG, MK, MN, MW, MX, MY, MZ, NA, NG, NI, NO, NZ, OM, PA, PE, PG, PH, PL, PT, QA, RO, RS, RU, RW, SA, SC, SD, SE, SG, SK, SL, SM, ST, SV, SY, TH, TJ, TM, TN, TR, TT, TZ, UA, UG, US, UZ, VC, VN, ZA, ZM, ZWc (84) $E5(I f )] $ -$%g2% M): ARIPO (BW, GH, GM, KE, LR, LS, MW, MZ, NA, RW, SD, SL, ST, SZ, TZ, UG, ZM, ZW), RIl (AM, AZ, BY, KG, KZ, RU, TJ, TM), JII (AL, AT, BE, BG, CH, CY, CZ, DE, DK, EE, ES, Fl, FR, GB, GR, HR, HU, IE, IS, IT, LT, LU, LV, MC, MK, MT, NL, NO, PL, PT, RO, RS, SE, SI, SK, SM, TR), OAPI (BF, BJ, CF, CG, CI, CM, GA, GN, GQ, GW, KM, ML, MR, NE, SN, TD, TG). - ttK [ I d21*(3)) (57)iALR: aPR)]t J'$$SEHA ftIW @ L9$TL A fIAf4Ri&$, MLI Tl T f T -i3##i #UA M TL-lSEMj- 4 , A tW96tEN 9 MJ1 M iMT -i E&A +, EM $20l- )] I$ I lj mfg)M Ji]Qft$$9 tT, A j$ A ' f6jA l' ' A U)Ai

Porous medium permeability prediction method based on machine image intelligent learning

The invention relates to a method for analyzing a CT scanning result based on a box counting method, which aims to solve problems of information loss and great result error generated in image processing in the prior art. The method comprises the steps that one, a computer reads all CT scanning pictures and performs binarization processing on all of the CT scanning pictures, and the binarization result of each picture is a two-dimensional matrix [A]; two, the two-dimensional matrixes [A], which are acquired in the step one, of all pictures are arranged according to a height sequence to obtain athree-dimensional matrix; three, the three-dimensional matrix [C] acquired in the step two is divided into L three-dimensional sub-matrixes according to the memory capacity of the computer; four, performing box counting on the L three-dimensional sub-matrixes divided in the step three to obtain box counting result sequences; and five, the box counting result sequences of the three-dimensional sub-matrixes are integrated to obtain a score dimension of the CT scanning result. The method is applied to the field of industrial CT scanning.

Method for analyzing CT scanning result based on box counting method

The invention belongs to the technical field of scientific research on petroleum and relates to a CO2-brine contact angle measuring method based on micro-focus X-ray CT. The measuring method comprises a rock core displacement process and a micro-focus X-ray CT shooting and image post-processing process. Pore-level in-situ measurement of CO2-brine contact angles is realized with the method. The CO2-brine contact angles in different positions and in different pores of rock cores can be measured after one-time shooting, and compared with traditional methods, the method consumes less time and is smaller in measurement result error. The method is applied to actual rock cores instead of smooth and ideal materials, and effects caused by surface roughness, mineral composition, heterogeneity of pore structures and the like on the CO2-brine contact angles are considered. The method is applicable to measurement of CO2-brine balance contact angles, retreat contact angles and advance contact angles and wide in measurement range. Measurement results are directly used as input parameters for numerical simulation and can be popularized to contact angle measurement of any gas-liquid-solid or liquid-liquid-solid three-phase systems.

CO2-brine contact angle measuring method based on micro-focus X-ray CT

The invention belongs to the technical field of petroleum and geological science and provides a permeability predication method based on CT (computed tomography) images The method comprises steps as follows: CT scanning: an actual rock sample is scanned through industrial x-ray CT, and a digital rock core image of the actual rock sample is obtained and is cut; the digital rock core image is subjected to binarization, and a skeleton and pores of the digital rock core image are obtained; a representative elementary volume of the digital rock core image is determined; seepage simulation: an absolute permeability value and a relative permeability value are predication values of actual rock permeability According to the permeability predication method, the process is simple, and multiple measurement times of the rock permeability under different geological conditions are easy to realize; by means of the measurement method, the permeability of rock with anisotropy can be accurately predicated; a measurement result can be directly taken as an input parameter of numerical simulation, and the measurement method is applicable to rock permeability predication of any gas-liquid-solid or liquid-liquid-solid three-phase or multi-phase system The method can also be popularized to predication of other physical properties of rock

Permeability predication method based on CT (computed tomography) images

The invention relates to a method for measuring a convective mixing process velocity field in a porous medium based on nuclear magnetic resonance imaging, and the method belongs to the technical field of convective mixing process velocity field measurement. The method comprises the steps of carrying out upper-lower layered saturation on two kinds of solutions with different densities in the porous medium at first, placing a sand-filled pipe saturating the two kinds of solutions with different densities in an inverted manner and then placing the sand-filled pipe into a nuclear magnetic probe quickly, adopting a spin echo sequence method added with phase encoding gradient pulses to obtain a proton density image of a fluid and converting the proton density image into a phase image, making difference between the phase image and a stationary state phase image under the same pulsed gradient to obtain a phase shifting image, and measuring to obtain a porous medium convective mixing process velocity field by adopting a phase method. The method realizes the unconventional fluid distribution situation required by convective mixing, is applied to the nuclear magnetic resonance imaging technology, carries out visual observation on the convective mixing process velocity field by non-contact and non-interference means, and does not disturb flow of the fluid.

Method for measuring convective mixing process velocity field in porous medium based on nuclear magnetic resonance imaging

The invention discloses a sand filling type clamp for an industrial X-Ray CT (computed tomography) imaging system, and belongs to the technical field of scientific petroleum researches The sand filling type clamp is used for doing simulation researches on seepage and relevant characteristics of multi-phase and multi-component fluid in a multihole medium; designed pressure is 0-15MPa, and designed temperature is 0-50 DEG C The sand filling type clamp mainly comprises a base, an inner pipe, an outer pipe, an upper end socket, an end cover, a metal filtering net, a pressing pad and a rubber coil, wherein the inner pipe, the upper end socket and a lower end socket form a hollow high-pressure-resistant cavity filled with the multihole medium such as glass sand, quartz sand or clay; a heat preservation band winds the outer wall of the outer pipe, and the heat preservation band, the end cover and the base form a circulating temperature control cavity for enabling circulating liquid to flow through The specific execution mode comprises a simulation rock core preparation process, a temperature control system operation process and a displacement or seepage experiment operation process The sand filling type clamp is simple in structure, convenient to assemble and disassemble and high in sealing property, can be filled for multiple times and can be used repeatedly

Sand filling type clamp for industrial X-Ray CT (computed tomography) imaging

The invention discloses an improved Hele-Shaw box and a two-phase fluid density difference convective mixing experimental system formed by the improved Hele-Shaw box The experimental system comprises a CCD camera, the improved vertical type Hele-Shaw box, and an area light source By adopting the improved vertical type Hele-Shaw box, a lower layer fluid space sealed by a rotary switch is filled with small density fluid, and an upper layer fluid space is filled with large density fluid The CCD camera, the improved vertical type Hele-Shaw box, and the area light source are disposed in a camera bellows The rotary switch is used to rotate a rotating shaft arc surface to a gap between two layers of parallel light-transmitting materials to seal lower layer fluid The large density fluid is disposed in the upper part of the Hele-Shaw box in a filled manner The switch is opened, and the upper layer fluid and the lower layer fluid are contacted with each other, and a convective mixing experiment caused by a fluid-fluid two-phase fluid density difference is started, and at the same time, the CCD camera starts to shoot the images of the two-phase liquid convective mixing process The experimental system has advantages of simple structure, convenient operation, accurate timing, and applicability in subsequent researching of interphase boundary changing, fingering generation development time, fingering numbers and other characteristic parameters during convective mixing process

Improved Hele-Shaw box and two-phase fluid density difference convective mixing experimental system formed by improved Hele-Shaw box

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