Seismic Data Interpretation and Petrophysical Analysis of Kabirwala Area Tola (01) Well, Central Indus Basin, Pakistan

: Well logging is a signiﬁcant procedure that assists geophysicists and geologists with making predictions regarding boreholes and efﬁciently utilizing and optimizing the drilling process. The current study area is positioned in the Punjab Territory of Pakistan, and the geographic coordinates are 30020 (cid:48) 10 N and 70043 (cid:48) 30 E. The objective of the current research work was to interpret the subsurface structure and reservoir characteristics of the Kabirwala area Tola (01) well, which is located in the Punjab platform, Central Indus Basin, utilizing 2D seismic and well log data. Formation evaluation for hydrocarbon potential using the reservoir properties is performed in this study. For the marked zone of interest, the study also focuses on evaluating the average water saturation, average total porosity, average effective porosity, and net pay thickness. The results of the study show a spotted horizon stone with respect to time and depth as follows: Dunghan formation, 0.9 s and 1080.46 m; Cretaceous Samana Suk formation, 0.96 s and 1174.05 m; Datta formation, 1.08 s and 1400 m; and Warcha formation, 1.24 s and 1810 m. Based on the interpretation of well logs, the purpose of petrophysical analysis was to identify hydrocarbon-bearing zones in the study area. Gamma ray, spontaneous potential, resistivity, neutron, and density log data were utilized. The high zone present in the east–west part of the contour maps may be a possible location of hydrocarbon entrapment, which is further conﬁrmed by the presence of the Tola-01 well.


Introduction
Well logging is a significant tool that assists geophysicists and geologists with making predictions regarding hydrocarbon reservoirs and provides important information such as rock composition, characteristics, and integrity as well as the presence of fluids and hydrocarbon. The collected data from well logs can be utilized to perform feasibility studies relevant to the physical properties of the area of interest under geophysical work. The oil and gas industries utilize estimated petrophysical parameters from well log data, which is a crucial part of the exploration and production processes [1,2]. These petrophysical parameters also assist with interpreting the subsurface for detection and estimation of hydrocarbon reservoirs. Furthermore, the oil and gas industries mostly use wireline logging to achieve continuous records regarding formation rock properties [3][4][5].
Seismic data interpretation is commonly used for hydrocarbon exploration and development studies [6][7][8][9]. The interpretation of seismic data requires an understanding of the subsurface formations and wave propagation effects. Seismic data consist of reflections that represent the geological structures as well as the reservoir stratigraphy, fabric, and fluid content. Al-Shuhail et al. [3,5] presented 2D viscoelastic models of the Ghawar and central fields of Saudi Arabia and created corresponding multi-component synthetic seismic  [11] Volume of shale, porosity, hydrocarbon saturation, water saturation 3D Yes Yes Discovery of hydrocarbon reserve resource accumulations in Pennay field [12] Effective porosity, clay content, and water saturation -Yes Yes Proposal of joint estimation of petrophysical properties combining statistical rock physics and Bayesian seismic inversion  [13] Volume 3D Yes Yes Estimation of brittleness of resource plays in 3D by integrating petrophysics and seismic data analysis [14] Joint probability function, porosity, thickness 3D Yes Yes Estimation procedure for extrapolating wireline data from existing wells using geostatistical inversion of post-stack 3D seismic data [15] Porosity, water saturation and hydrocarbon saturation

3D
Yes Yes Determination of reservoir properties and estimated volume of hydrocarbons within reservoirs [16] Porosity, net-to-gross, water saturation, hydrocarbon saturation

3D
Yes Yes Reserve evaluation of hydrocarbonbearing sands [17] Volume of shale, porosity, water saturation, formation water resistivity, and hydrocarbon saturation

2D
Yes Yes Structural interpretation and hydrocarbon potential of Balkassar oil field [18] Density, neutron, self-potential, and resistivity

2D Yes Yes
Structural interpretation of Joya Mair oil field using 2D seismic data and petrophysical analysis [19] Porosity, permeability, moderate net to gross, and low water saturation

3D Yes Yes
Application of 3D static model using 3D seismic and well log data for optimization and development of hydrocarbon potential in KN field of Niger Delta Province The current research work is organized as follows: Section 2 describes the tectonics of the proposed area, Section 3 describes the generalized stratigraphy of the area, and Section 4 presents a comprehensive analysis of the seismic interpretation and the well log analysis, Section 5 consists of a detailed petrophysical analysis, Section 6 presents the discussion, and finally, Section 7 presents the conclusions of the current research work.  [20]). (c). Generalized stratigraphic chart of the study area [21]. (d). Seismic section with marked horizon.

Tectonics of the Area
There are three subdivisions of the Central Indus Basin (CIB): the Punjab platfor Sulaiman fold belt, and Sulaiman depression. The Punjab platform is located at the eas west of the Sulaiman depression and fold belt, as shown in the structural map in Figu 1b [8]. The Punjab platform is a westward-dipping monocline covered with unconso dated Quaternary deposits with a maximum thickness of about 500 m [9], and the area almost all desert and neglected surface outcrops [10]. As shown in Figure 1b, Sargod high is at the north of the CIB, Indian Shield is at the east, an axial belt is at the west, a finally Sukker Rift is located at the south [10]. The Punjab platform was the least affect during Himalayan orogeny; therefore, it possesses non-tectonic origin structures [11]. also has no exposure to bedrocks. The primogenital rock existing in the basin is count  [20]). (c). Generalized stratigraphic chart of the study area [21]. (d). Seismic section with marked horizon.

Tectonics of the Area
There are three subdivisions of the Central Indus Basin (CIB): the Punjab platform, Sulaiman fold belt, and Sulaiman depression. The Punjab platform is located at the east-west of the Sulaiman depression and fold belt, as shown in the structural map in Figure 1b [8]. The Punjab platform is a westward-dipping monocline covered with unconsolidated Quaternary deposits with a maximum thickness of about 500 m [9], and the area is almost all desert and neglected surface outcrops [10]. As shown in Figure 1b, Sargodha high is at the north of the CIB, Indian Shield is at the east, an axial belt is at the west, and finally Sukker Rift is located at the south [10]. The Punjab platform was the least affected during Himalayan orogeny; therefore, it possesses non-tectonic origin structures [11]. It also has no exposure to bedrocks. The primogenital rock existing in the basin is counted in the Triassic age. Owing to the absence of active tectonic elements in the CIB, it is almost stable [12].

Generalized Stratigraphy of the Area
Stratigraphy is mainly concerned with the study of rock layers (strata) and layering (stratification). Stratigraphy has two related subfields: lithostratigraphy and biostratigraphy. The generalized stratigraphy of the study area is discussed in the following subsections.

Pliocene/Miocene Stratigraphy
The Pliocene/Miocene stratigraphy of the area includes the following formations: Its lithology is constituted of sandstone with dependent clay as well as conglomerate. Its topmost association is with Dhok Pathan formation, which is transitionary. The age is Late Miocene.

Chinji Formation
Its lithology constitutes of red clay with dependent ash gray or brownish-gray sandstone. It is exclusively limited to the southern bisection of the eastern Suleiman range and is not elaborated in the repose of the Lower Indus Basin. It is substantially superimposed beside the Nagri formation. The age is Late Miocene [21].

Oligocene Stratigraphy
The Oligocene stratigraphy of the area includes the following formation:

Nari Formation
The name "Nari series", derived from the Nari River in the Kirthar range, was introduced by Khokhar et al. [22]. The Nari formation consists of sandstone, shale, and subordinate limestone. The lower part of the formation, the Nal member, is predominantly composed of crystalline limestone, which is white to gray, brown or yellow shelly, nodular or rough surfaced, thin to thick bedded, and even massive. Thin stringers of dark shale and of thin bedded and fine-grained brown sandstone are also present.

Eocene Stratigraphy
The Eocene stratigraphy of the area includes the following formations:

Habib Rahi Formation
The Habib Rahi formation was formalized by the Stratigraphic Committee from Habib Rahi limestone of Tainsh et al. [23]. It can be described as a grayish-brown and buff hard limestone that is weathering white. It is fine-grained, thin-bedded, dominantly argillaceous, and in a few places grades into marl.

Pirkoh Formation
The Pirkoh limestone member was introduced by Hemphill and Kidwai [24]. Rehman et al. [25] defined the formation as follows: lithologically, the Pirkoh formation consists of limestone that is light gray to chalky white, buff to brown, fine-grained, mostly thin and regularly bedded, and often argillaceous. The formation commonly contains subordinate beds of soft, shaly limestone, and dark gray calcareous claystone.

Paleocene Stratigraphy
The Paleocene stratigraphy of the area includes the following formations:

Ghazij Sui Member
The overall lithology in the early Eocene episode is shale, as well as marl in the Lower Indus Basin, along with adjacent areas of the axial belt. The Ghazij Sui member consists of Kirthar formation. The Kirthar formation is separable into four components in sections of eastern Sulaiman province as Habib Rahi limestone, Sirki, Pir koh, and Drazinda components [26].

Dunghan Formation
The Dunghan formation was familiarized by Kazmi [27]. Malkani et al. [28] nominated the order portion to be adjacent to Harnai (latitude 300 08 38 N, longitude 670 59 33 E) and renewed the close rank Dunghan formation. It is constituted of limestone, shale, and marl. The limestone is gray to yellowish, fine to intermediate bedded with conglomerates. The shale is gray and khaki as well as calcareous. The marl is brown to gray, fine to intermediate bedded, and fine-grained. Sideward, these formational facies are dissimilar at places with dense limestone precipitates, while at some positions, there is insignificant limestone evidence. The Sui main is the topmost portion of the Dunghan limestone because of its fluctuating manner. It is dense in the Zindapir, Duki, Sanjawi, Harand, and Mughal Kot portions, but it is minute in the Rakhi Gaj and in Mekhtar regions. Petroleum evidence is common in this formation, notably in the Khatan portion [27]. Adjacent to the axial belt, it has disconformity at the base, while the topmost association with the Shaheed Ghat formation is transitionary. It has many mega forms. Its age is deliberated as Late Paleocene, notably excessively to Early Eocene. Even though it is prolonged, all the Paleocene in the Ziarat region, as well as the axial belt area where the Sangiali and Rakhi Gaj formations, i.e., the lower, along with the middle Sangiali group, is not promoted. For instance, the Ziarat Laterite exhibited K-T boundary is contacted through the Parh along the Dunghan formation [28].

Ranikot Formation
The Ranikot formation was subsequently nominated as the Ranikot fortress in the Laki range adjacent to Sindh. Furthermore, the Ranikot group is recognized as infra-Nummulitic. The Ranikot formation has been segregated into three formations, recognized as the Khadro, Bara (lower Ranikot sandstone), and Lakhra (upper Ranikot limestone) formations. The lower part has sandstone of brownish yellow color and shale along with limestone. Correspondingly, the lower Ranikot has diversified sandstone and shale along with gray to brown limestone, and the shale is also present in the Lakhra formation [29].

Cretaceous Stratigraphy
The Cretaceous stratigraphy of the area includes the following formations:

Sembar Formation
The name "Sembar formation" was introduced by Williams [30], after Sembar Pass in the Mari hills, to include the lower part of the "Belemnite beds" and "Belemnite shales". The "Belemnite beds" of Oldham also include the overlying Goru formation and the Parh limestone. According to Fatmi [31], the Sembar formation consists of black silty shale with interbeds of black siltstone and nodular rusty weathering argillaceous limestone beds or concretions. The upper contact is generally gradational with the Goru formation.

Goru Formation
The name "Goru formation" was introduced by Williams [30]. As described by Fatmi [31], the Goru formation consists of inter bedded limestone, shale, and siltstone. The limestone is fine-grained, thin-bedded, and light to medium gray and olive gray. The interbedded shale and siltstone are gray, greenish gray, and locally maroon in color.

Parh Limestone
The term "Parh" was introduced by Blanford [32]. The Parh limestone, as described by Fatmi [31], is a lithologically very distinct unit. It is a hard, light gray, white, cream, olive green, thin-to medium-bedded, lithographic to porcellaneous, argillaceous and occasionally platy to slabby limestone with subordinate calcareous shale and marl intercalations. The formation is correlated with the Kawagarh formation of Kohat-Potwar province. The lower contact is with the Goru formation, while the upper contact is with the Moghal Kot formation.

Moghal Kot Formation
The term "Mughal Kot formation" was applied by Williams [30]. Lithologically, as stated by Fatmi [31], the formation comprises dark gray calcareous mudstone and calcareous shale with intercalations of quartos sandstone and light gray argillaceous limestone.

Pab Sandstone
The term "Pab sandstone" was introduced by Eschard et al. [33]. The formation typically consists of quartos sandstone, which is white, cream, or brown, weathering yellow brown, medium to coarse-grained thick bedded to massive, and shows crossstratification. Some marl and argillaceous limestone, similar to that of the Parh limestone, are found intercalated.

Jurassic Stratigraphy
The Jurassic stratigraphy of the area includes the following formations:

Samana Suk Formation
The name came from a mountain peak in the Samana range, which is revealed. It is constituted of limestone that is absolutely fine-grained and clay, along with sand. The lower association is with the Shinawri and topmost with the Chichali formation. The environment of precipitation is slightly nautical [34].

Shinawri Formation
It lies in Shinawri village in the western part of the Samana range. It has sparse to well-stratified limestone nodular marl, calcareous along with non-calcareous shale, and calcareous sandstone. Its lower association is conformable with the Datta and topmost with the Samana Suk formation. Its environment of precipitation is nautical [35].

Datta Formation
It is positioned in Datta Nala of the Surghar range. The lithology is constituted of arenaceous, siltstone, and shale. It has no peculiar petrified report; however, some carbonaceous remnants are present. Based on the law of superposition, its age is Early Jurassic. Datta shale acted as the superior originator rock and sandstone as the superior reservoir rock. Its environment of precipitation is deltaic [36].

Triassic Stratigraphy
The Triassic stratigraphy of the area includes the following formations:

Kingriali Formation
It is positioned in Zaluch Nala, Tapan Wahan, at the Khisor range. It has two components, nominated as the Doya component, which is constituted of sandstone, dolomite, dolomitic sandstone, and shale, and the Vanjari component, which is mainly dolomitic. Its environment of precipitation is tidal flats [37].

Tredian Formation
It has also two components, Landa and Khatkiari. The Landa component's lithology is sandstone along with shale, while the Khatkiari component is constituted of compacted white-appearing sandstone. Its environment of precipitation is fluvial (non-marine) [38].

Permian Stratigraphy
The Permian stratigraphy of the area includes the following formations: The Amb formation is positioned in Amb village. It has three units: the lower unit is constituted of shale, the intermediate is constituted of limestone, and the topmost is constituted of shale. As a result of the known index of petrified fusulinids, its age is nominated as Late Permian. Its lower association is conformable with the Sardhai and topmost with the Wargal formation. Its environment of precipitation is nautical [39].

Sardhai Formation
The Sardhai formation is positioned in Sardhai Gorge. It is constituted of clays of various appearances with a minute extent of sandstone and siltstone. The topmost part of Sardhai is calcareous. The limestone strata have well-improved petrification. Its environment of precipitation is fluvial delta. The age is Early-Middle Permian [40].

Warcha Formation
Its lithology is constituted of intermediate to coarse-grained zigzag stratified sandstone, conglomerate in places, and interbeds of shale are also present. The pebbles of the unit are particularly of granite of pink appearance along with quartzite. Based on the law of superposition, its age is Early Permian [41].
All of these formations overlay the Salt Range formation, Khewra sandstone, and Kussak formation (composed of sandstone and glauconitic shale), respectively, as shown in Figure 1c.

Seismic Data Interpretation
Seismic interpretation is the description of the subsurface geological features from seismic data collected during the extraction process. The drilling team can perform the interpretation of seismic data to determine the structural models beneath the earth's surface. Amplitude, frequency, and phase are the main seismic attributes that are generally used in the interpretation process.
The main aim of interpretation is to identify the different reflectors or horizons as interfaces between different geological formations. Interpretation is mainly required in order to obtain structural and stratigraphic information. During interpretation, the horizons and faults are marked for better representation. In the beginning, interpretation was done manually on paper sections, but nowadays, it is done with the help of powerful computer systems. With graphic support, computer-aided interpretation systems are used in the industry, as shown in Figure 1d. Seismic sections can forecast configurations of up to tens of kilometers. A fault with throw that is less than one-quarter of the wavelength of the seismic wave will be very complicated to mark out in the seismic section [42]. The current study area is situated in an extensional regime, so the general structure is normal related, i.e., horst and graben structure. A normal fault will progress due to the extensional regime. Overall, four faults are apparent on the seismic section, which increases the complexity of the research area. These are marked upon the detection of abrupt variations in the condition of reflectors and misrepresentation or disappearance of the reflection underneath the faults.
The purpose of interpretation is to understand how these structures are formed, and it is necessary for mapping and marking the horizons above and below the target zone. The strata in an exposure or outcropping of sedimentary rock can range from layers as thin as paper, which are known as lamina (plural: laminae or laminations), to beds tens of feet thick. Generally, the more stable and consistent the environmental conditions during deposition, the thicker the strata will be.
The seismic interpretation procedure consists of various tracks reserved to find an explanation of the seismic sector on the subject of all stratigraphic structures and sequences [13]. In the oil and gas industries, the critical objectives of seismic interpretation are to detect hydrocarbon pathways and explore its flow [14]. In the case of the Kabirwala lines, the reflectors are constituted to be fundamentally flat; thus, a conduit cannot be assembled for hydrocarbon migration along with maturation. Seismic interpretation is also necessary for selecting the appropriate geological reservoir for long-term CO 2 sequestration [43][44][45][46][47][48][49].
The basic interpretation stages are based on seismic well log data of the Tola-01 well in the Kabirwala area and on seismic lines. As given in Tables 2 and 3, five migrated seismic lines, navigation data of seismic lines, well log data, and formation tops for the Tola-01 well were accessible for this project. Seismic data analysis consists of stratigraphic and structural analysis. The structure and stratigraphy of the subsurface is evaluated from the seismic reflection data [50]. Seismic interpretation involves converting velocity and time into the depth of subsurface reflecting interfaces to translate seismic data into geological images [5].  Formation density (RHOB) gm/cm 3 4 Resistivity (MSFL) (LLD) (LLS) Ω.m 5 Gamma ray (GR) API 6 Spontaneous potential (SP) mV 7 Caliper (CALI) Inches Figure 2a points out the "Base Map" of the study area (Tola-01 well), which is located in the Punjab platform of Central Indus Basin (CIB). The key purpose of the "Base Map" is to point out the particular direction of the seismic lines, shot points, as well as the well position on the seismic line. In the current study, the "Base Map" points out two strike lines and three dip lines. The two strike lines have the shooting trend from the north to south direction. However, the three dip lines have the shooting trend from the east to west direction. The location of the Tola (1) well is added in the base map. The Tola (1) well is located at 875-KBR-230 line in the Base Map. Owing to the seismic data interpretation, four reflectors are defined in the seismic sections. The well tops of Tola-01 are utilized for the correlation. The horizons are the Dunghan, Samana Suk, Datta, and Warcha formations, as shown in Table 4. Similarly, the horizons of seismic lines are given in detail in  The Tola (01) well is located on the 875-KBR-230 line in the base map. The 875-KBR-230 line is used as a reference for marking our seismic sections. The well tops of the Tola-01 well were used to locate the required reflectors on the seismic section. The well tops data give us the formation tops with a required depth. As far as the well tops of the Tola-01 well are concerned, the tops of the required formations, which are Dunghan, Samana suk, Datta and Warcha, are given in Tables 4 and 5.
The fit line curve created from the velocity windows calculation and the graph help us find the time against the depth on the time section. The time values of the prescribed formations have been obtained using the time depth chart. Then, these time values obtained from the time-depth chart of well Tola-01 were projected on the seismic line 844-KBR-230. Furthermore, a line is drawn from the prescribed shot point crossways on the seismic traces toward the second time vertically, and the values of the time are also pinpointed on the well line over the seismic line. The time picked on the seismic line is shown in Tables 4 and 5. For labeling the seismic horizons and faults, the time of each reflector will be recognized at various shot points, and the travel time of each reflector will be marked along with faults on the y-axis, in contrast to the shot points on the x-axis.
In the present study, there are four marked reflectors with normal faults on each line. Gridding of these lines was assembled for a contouring plan as well as to interpret the configuration model of these lines for the arrangement of contouring. The horst along with the graben configurations that existed on the seismic sections (

Seismic Time and Depth Sections
The first step is to solve the velocity windows, which are given on the top of the seismic lines. As shown in the Base Map in Figure 2a, the Tola-01 well lies on the seismic line 875-KBR-230; therefore, the velocity window is solved for the KBR-230 seismic section. On the velocity window, one column is for the time in milliseconds, and the other column is for the RMS (root-mean-square) velocity. Then, the RMS velocity is multiplied with the one-way travel time in milliseconds to give the depth by using the formula S = VT. The one-way travel time is calculated by dividing the time by 2. This column gives the depth of each time during the recording of a seismic wave traveling under the surface. For more insight into the velocity window, the depth needs to be plotted against the time window [51,52]. The velocity windows are first solved to obtain the time values, and then, the depth is plotted on the horizontal axis against the time on the vertical axis. By using the reasoning that the subsurface structures can be predicted by transforming the time into depth, the TVT chart is constructed. The perception of transforming time to depth is accurate to point out the subsurface structures because the structure is flat and the map is in terms of the two-way travel time (TWT) of sound waves. Thus, a map of the seismic time section is proposed to point out the structure in the subsurface. The depth is plotted with time, as shown in Figure 2b

Marking Reflectors
To interpret the seismic sections, it is important to point out a particular well on a specific line to be used as a reference [53]. In this study, the seismic line and the well tops of the Tola-01 well were used to pinpoint the prescribed reflectors on that particular seismic section. Then, the nature of the marked reflectors is traced toward the seismic section used in this study. The well tops of Tola-01 of the prescribed formation are Dunghan, Samana Suk, Datta, and Warcha formations. The Punjab platform is tectonically less influenced area because of its greater outdistance from the belt, as shown in Tables 4 and 5.

Time and Depth Contour Maps and Surfaces Maps
A mark that joins the track of equivalent values is called a contour mark or line. Such drawings display the sharpness of angles (slope), the promotion top of the subsurface of the deposited rock stratum (elevation), and the corresponding two-way travel time of the prospect in milliseconds [54].

Time Contour Maps
A contour map is simply defined as a line that exhibits parameters on a 2D map, such as depth or elevation [20]. With the help of time rates, the contours are created to show the time of the waves that reflect back from pronounced condensed reflectors or strata due to the density/velocity contrast or simply acoustic impedance. The time contour is initiated on a map for every reflector.

Marking Reflectors
To interpret the seismic sections, it is important to point out a particular well on a specific line to be used as a reference [53]. In this study, the seismic line and the well tops of the Tola-01 well were used to pinpoint the prescribed reflectors on that particular seismic section. Then, the nature of the marked reflectors is traced toward the seismic section used in this study. The well tops of Tola-01 of the prescribed formation are Dunghan, Samana Suk, Datta, and Warcha formations. The Punjab platform is tectonically less influenced area because of its greater outdistance from the belt, as shown in Tables 4 and 5.

Time and Depth Contour Maps and Surfaces Maps
A mark that joins the track of equivalent values is called a contour mark or line. Such drawings display the sharpness of angles (slope), the promotion top of the subsurface of the deposited rock stratum (elevation), and the corresponding two-way travel time of the prospect in milliseconds [54].

Time Contour Maps
A contour map is simply defined as a line that exhibits parameters on a 2D map, such as depth or elevation [20]. With the help of time rates, the contours are created to show the time of the waves that reflect back from pronounced condensed reflectors or strata due to the density/velocity contrast or simply acoustic impedance. The time contour is initiated on a map for every reflector. In our research, the reflectors of relevance are the Dunghan, Samana Suk, Datta, and Warcha formations. The time contour maps of the four essential reflectors on five seismic sections are projected on the Base Map. Justified to the depth along with other diverging capacities in the path of the traveling waves, the reflection time is further computed in order to give an idea about the structures and the time delay of the seismic wave feedback.

Depth Contour Maps
A depth contour map points out the structures of the area and contributes to the overall information about the depth along with its range of precise formation [21]. The given depth contour maps are constructed with the help of the reflection time rates of the seismic lines of the Kabirwala area, which contains 875-KBR 231, 875-KBR-230, 875-KBR-229, 875-KBR-221, and 875-KBR-220. On the seismic section, there are four reflectors: Dunghan, Samana Suk, Datta, and Warcha formations. It is assured by the contour maps that the reflectors are laterally flat, which can be seen in their patterns. These reflectors are marked as T1, T2, T3, and T4 on the seismic sections along with the depth contour graphs of these reflectors. For a single depth value, the depth contour map points out the same depth contour line, and the contour contributes to help us build a three-dimensional structure of a horizon showing its depth as a surface.

Time Contour and Time Surfaces Maps of Dunghan Formation
The time contour map of the Dunghan formation points out a monocline structure dipping in the eastward orientation. The reflection time increases from 0.93 to 1.14 s, as shown in Figure 8a. The time contour surface of the Dunghan formation was generated by joining the points of equal time. These time values were assigned a color bar, which can be used as a guide for interpretation. On the color bar, red shows the shallowest point, and purple-blue shows the deepest point (Figure 8b). The 3D view of the particular formation surface helps to comprehend the monocline structure in the Punjab platform region northward.

Time Contour and Time Surfaces Maps of Samana Suk Formation
The time contour map of the Samana Suk formation also points toward the monocline structure dipping moderately in the eastward direction. The increase in reflection time is from 0.97 to 1.19 sec, which is shown in Figure 9a

Time Contour and Time Surfaces Maps of Samana Suk Formation
The time contour map of the Samana Suk formation also points toward the monocline structure dipping moderately in the eastward direction. The increase in reflection time is from 0.97 to 1.19 s, which is shown in Figure 9a

Time Contour and Time Surfaces Maps of Datta Formation
The time contour map of the Datta formation also has a monocline structure, simila to the other two formations, describing the characteristics of the Punjab platform. The in

Time Contour and Time Surfaces Maps of Datta Formation
The time contour map of the Datta formation also has a monocline structure, similar to the other two formations, describing the characteristics of the Punjab platform. The increase in reflection time is from 1.02 to 1.28 sec, which is shown in Figure 10a. The time contour surface of the Datta formation was generated by joining the points of equal time. These time values were assigned a color bar, which can be used as a guide for interpretation. On the color bar, red shows the shallowest point and purple-blue shows the deepest point (Figure 10b).

Time Contour and Time Surfaces Maps of Warcha Formation
The time contour map of the Warcha formation also points toward the monocline structure, dipping moderately in the eastward direction. The increase in reflection time is from 1.34 to 1.64 sec, as shown in Figure 11a. The time contour surface of the Warcha formation was generated by joining the points of equal time. These time values were assigned a color bar, which can be used as a guide for interpretation. On the color bar, red shows the shallowest point and purple-blue shows the deepest point (Figure 11b).

Time Contour and Time Surfaces Maps of Warcha Formation
The time contour map of the Warcha formation also points toward the monocline structure, dipping moderately in the eastward direction. The increase in reflection time is from 1.34 to 1.64 s, as shown in Figure 11a. The time contour surface of the Warcha formation was generated by joining the points of equal time. These time values were assigned a color bar, which can be used as a guide for interpretation. On the color bar, red shows the shallowest point and purple-blue shows the deepest point (Figure 11b).

Depth Contour and Depth Surfaces Maps of Dunghan Formation
In comparison to the time contour map, the depth contour map of the Dunghan formation contributes to the same diagram of the dipping monocline structure of the Punjab platform area of the CIB. The depth value of the Dunghan formation plunges eastward and the decrease in depth value is from 1370 to 1110 m, as shown in Figure 12a. The depth contour surface of the Dunghan formation was generated by joining the points of equal depth. These depth values were assigned a color bar, which can be used as a guide for interpretation. On the color bar, red shows the shallowest point and purple-blue shows the deepest point (Figure 12b).

Depth Contour and Depth Surfaces Maps of Dunghan Formation
In comparison to the time contour map, the depth contour map of the Dunghan formation contributes to the same diagram of the dipping monocline structure of the Punjab platform area of the CIB. The depth value of the Dunghan formation plunges eastward and the decrease in depth value is from 1370 to 1110 m, as shown in Figure 12a. The depth contour surface of the Dunghan formation was generated by joining the points of equal depth. These depth values were assigned a color bar, which can be used as a guide for interpretation. On the color bar, red shows the shallowest point and purple-blue shows the deepest point (Figure 12b).

Depth Contour and Depth Surfaces Maps of Samana Suk Formation
The depth contour map of the Samana Suk formation points out descending depth northward from 1450 to 1180 m, as shown in Figure 13a. The depth contour surface of the Samana Suk formation was generated by joining the points of equal depth. These depth values were assigned a color bar, which can be used as a guide for interpretation. On the color bar, red shows the shallowest point and purple-blue shows the deepest point ( Figure  13b).

Depth Contour and Depth Surfaces Maps of Samana Suk Formation
The depth contour map of the Samana Suk formation points out descending depth northward from 1450 to 1180 m, as shown in Figure 13a. The depth contour surface of the Samana Suk formation was generated by joining the points of equal depth. These depth values were assigned a color bar, which can be used as a guide for interpretation. On the color bar, red shows the shallowest point and purple-blue shows the deepest point (Figure 13b).

Depth Contour and Depth Surfaces Maps of Datta Formation
The depth contour map of the Datta formation uses a similar template as the Samana Suk formation. The inclusive structure is the monocline structure of the Punjab platform, even though fluctuating variations in depth are shown. The decrease in depth value is from 1660 to 1320 m, as shown in Figure 14a. The depth contour surface of the Datta formation was generated by joining the points of equal depth. These depth values were assigned a color bar, which can be used as a guide for interpretation. On the color bar, red shows the shallowest point and purple-blue shows the deepest point (Figure 14b).

Depth Contour and Depth Surfaces Maps of Datta Formation
The depth contour map of the Datta formation uses a similar template as the Samana Suk formation. The inclusive structure is the monocline structure of the Punjab platform, even though fluctuating variations in depth are shown. The decrease in depth value is from 1660 to 1320 m, as shown in Figure 14a. The depth contour surface of the Datta formation was generated by joining the points of equal depth. These depth values were assigned a color bar, which can be used as a guide for interpretation. On the color bar, red shows the shallowest point and purple-blue shows the deepest point (Figure 14b).

Depth Contour and Depth Surfaces Maps of Warcha Formation
The depth contour map of the Warcha formation uses a similar template as the Datta formation. The inclusive structure is the monocline structure of the Punjab platform, even though fluctuating variations in depth are shown. The decrease in depth value is from 2400 to 1940 m, as shown in Figure 15a. The depth contour surface of the Warcha formation was generated by joining the points of equal depth. These depth values were assigned a color bar, which can be used as a guide for interpretation. On the color bar, red shows the shallowest point and purple-blue shows the deepest point (Figure 15b).

Depth Contour and Depth Surfaces Maps of Warcha Formation
The depth contour map of the Warcha formation uses a similar template as the Datta formation. The inclusive structure is the monocline structure of the Punjab platform, even though fluctuating variations in depth are shown. The decrease in depth value is from 2400 to 1940 m, as shown in Figure 15a. The depth contour surface of the Warcha formation was generated by joining the points of equal depth. These depth values were assigned a color bar, which can be used as a guide for interpretation. On the color bar, red shows the shallowest point and purple-blue shows the deepest point (Figure 15b

Petrophysical Analysis
The main purpose of the petrophysical analysis is to retrieve information and data from the well logs [7,55,56]. Data utilized in the current research study include log curves of gamma ray, neutron, density, and resistivity logs. The clean zone is spotted by means of the gamma ray log. The separation in the resistivity curves is LLS (Letro-Log Shallow) MSFL (Micro Spherically Focused Log) and LLD (Letro-Log Deep) and the highest values of resistivity indicate the occurrence of hydrocarbons. The crossover between the neutron and density logs indicates the existence of hydrocarbons in the chosen clean zone. The subsequent zone of concentration is marked in Table 6, and the petrophysical parameters are shown in Table 7.

Petrophysical Analysis
The main purpose of the petrophysical analysis is to retrieve information and data from the well logs [7,55,56]. Data utilized in the current research study include log curves of gamma ray, neutron, density, and resistivity logs. The clean zone is spotted by means of the gamma ray log. The separation in the resistivity curves is LLS (Letro-Log Shallow) MSFL (Micro Spherically Focused Log) and LLD (Letro-Log Deep) and the highest values of resistivity indicate the occurrence of hydrocarbons. The crossover between the neutron and density logs indicates the existence of hydrocarbons in the chosen clean zone. The subsequent zone of concentration is marked in Table 6, and the petrophysical parameters are shown in Table 7.

Calculation of Volume of Shale
The volume of shale (Vsh) is also called the dirtiness of the reservoir. Figure 16 shows the Vsh considered in the zone of interest. The following equation was used for Vsh calculation: where GR log is the gamma ray log reading, GR max is the maximum gamma ray value, and GR min is the minimum gamma ray value.

Calculation of Volume of Shale
The volume of shale (Vsh) is also called the dirtiness of the reservoir. Figure 16 shows the Vsh considered in the zone of interest. The following equation was used for Vsh calculation: where GR log is the gamma ray log reading, GR max is the maximum gamma ray value, and GR min is the minimum gamma ray value.

Total Porosity
Basically, porosity is described as the quantity of void places (pores) relative to the overall volume of a rock [57]. These pores were formed in the rock during its deposition, which is termed as primary porosity, in contrast to the disintegration of particles through water or cracking, which is termed as secondary porosity. It is signified by ϕ and is often articulated in percentage. Porosity can be calculated using dissimilar techniques. In the current study, porosity was found using two methods [58]: density and neutron logs.

Total Porosity
Basically, porosity is described as the quantity of void places (pores) relative to the overall volume of a rock [57]. These pores were formed in the rock during its deposition, which is termed as primary porosity, in contrast to the disintegration of particles through water or cracking, which is termed as secondary porosity. It is signified by φ and is often articulated in percentage. Porosity can be calculated using dissimilar techniques. In the current study, porosity was found using two methods [58]: density and neutron logs.

Neutron Porosity
Neutron porosity records porosity, based on the influence of the accumulation on fast neutrons emanated by means of a source [59]. Hydrogen has an extreme impact on decelerating and catching neutrons. Hydrogen often resides in pore liquid, and the neutron porosity record reacts predominantly to porosity. The neutron porosity log is shown in Figure 18.

Density Porosity
The density record is converted to porosity through the following relation: where ΦD is density porosity, ρma is matrix density (g/cm 3 ), ρb is formation bulk density (log value) (g/cm 3 ), and ρfl is the density of the fluid saturating the rock adjacent to the drill-hole, which is frequently mud filtrate (g/cm 3 ). Incorrect values may perhaps result when conducting the analysis in evaporates or gas accumulations. They generate lower porosity values than expected authentic values. The density porosity log is shown in Figure 19.

Neutron Porosity
Neutron porosity records porosity, based on the influence of the accumulation on fast neutrons emanated by means of a source [59]. Hydrogen has an extreme impact on decelerating and catching neutrons. Hydrogen often resides in pore liquid, and the neutron porosity record reacts predominantly to porosity. The neutron porosity log is shown in Figure 18.

Neutron Porosity
Neutron porosity records porosity, based on the influence of the accumulation on fast neutrons emanated by means of a source [59]. Hydrogen has an extreme impact on decelerating and catching neutrons. Hydrogen often resides in pore liquid, and the neutron porosity record reacts predominantly to porosity. The neutron porosity log is shown in Figure 18.

Density Porosity
The density record is converted to porosity through the following relation: where ΦD is density porosity, ρma is matrix density (g/cm 3 ), ρb is formation bulk density (log value) (g/cm 3 ), and ρfl is the density of the fluid saturating the rock adjacent to the drill-hole, which is frequently mud filtrate (g/cm 3 ). Incorrect values may perhaps result when conducting the analysis in evaporates or gas accumulations. They generate lower porosity values than expected authentic values. The density porosity log is shown in Figure 19.

Density Porosity
The density record is converted to porosity through the following relation: where Φ D is density porosity, ρ ma is matrix density (g/cm 3 ), ρ b is formation bulk density (log value) (g/cm 3 ), and ρ fl is the density of the fluid saturating the rock adjacent to the drill-hole, which is frequently mud filtrate (g/cm 3 ). Incorrect values may perhaps result when conducting the analysis in evaporates or gas accumulations. They generate lower porosity values than expected authentic values. The density porosity log is shown in Figure 19. Appl. Sci. 2021, 11, x FOR PEER REVIEW 26 of 31 Figure 19. Density porosity variation along the depth.

Effective Porosity
Effective porosity (PHIE) is the summation of totally connected pores [7]. It is calculated by the following formula: The effective porosity log is shown in Figure 20.

Saturation of Water
Saturation of water (Sw) is calculated by using Archie's equation [26]: where Sw is saturation of water, Rw is resistivity of water, Rt is resistivity of the true zone, and φe is effective porosity; the log is shown in Figure 21.

Effective Porosity
Effective porosity (PHIE) is the summation of totally connected pores [7]. It is calculated by the following formula: The effective porosity log is shown in Figure 20.

Effective Porosity
Effective porosity (PHIE) is the summation of totally connected pores [7]. It is calculated by the following formula: The effective porosity log is shown in Figure 20.

Saturation of Water
Saturation of water (Sw) is calculated by using Archie's equation [26]: where Sw is saturation of water, Rw is resistivity of water, Rt is resistivity of the true zone, and φe is effective porosity; the log is shown in Figure 21.

Saturation of Water
Saturation of water (S w ) is calculated by using Archie's equation [26]: where S w is saturation of water, R w is resistivity of water, R t is resistivity of the true zone, and ϕ e is effective porosity; the log is shown in Figure 21.

Effective Porosity
Effective porosity (PHIE) is the summation of totally connected pores [7]. It is calculated by the following formula: The effective porosity log is shown in Figure 20.

Saturation of Water
Saturation of water (Sw) is calculated by using Archie's equation [26]: where Sw is saturation of water, Rw is resistivity of water, Rt is resistivity of the true zone, and φe is effective porosity; the log is shown in Figure 21.

Saturation of Hydrocarbon
Hydrocarbon saturation (S h ) is the most crucial feature due to the potential of the reservoir to generate hydrocarbons [27]. The result is shown in Figure 22, and the following formula was used for its calculation: Appl. Sci. 2021, 11, x FOR PEER REVIEW 27 of 31

Saturation of Hydrocarbon
Hydrocarbon saturation (Sh) is the most crucial feature due to the potential of the reservoir to generate hydrocarbons [27]. The result is shown in Figure 22, and the following formula was used for its calculation: In order to find out any hydrocarbon indicator (HI), all the well logs are shown together in Figure 23 in order to find out the hydrocarbon-bearing sand/carbonate and shale zones.  In order to find out any hydrocarbon indicator (HI), all the well logs are shown together in Figure 23 in order to find out the hydrocarbon-bearing sand/carbonate and shale zones.

Saturation of Hydrocarbon
Hydrocarbon saturation (Sh) is the most crucial feature due to the potential of the reservoir to generate hydrocarbons [27]. The result is shown in Figure 22, and the following formula was used for its calculation: In order to find out any hydrocarbon indicator (HI), all the well logs are shown together in Figure 23 in order to find out the hydrocarbon-bearing sand/carbonate and shale zones.

Discussion
In Figure 16, the volume of shale mostly varies from 40 to 80% up to the depth of 1115 m. This percentage shows that the lithology is partially clean and partially dirty and presents some presence of sand; therefore, it indicates a reservoir zone.
In Figure 20, effective porosity varies from 3 to 15% up to depths of 975 to 1115 m then decreases up to 1175 m, which shows that after 1115 m, compaction starts, which damages the interconnectivity of pores.
In Figure 21, the saturation of water lies almost in the range of 0-10%. Water saturation continuously changes with depth in this variation due to the fracture or compaction present in the formations. This is represented by the zone of less water saturation and high hydrocarbon saturation. Comparing Figures 21 and 22, hydrocarbon saturation and water saturation, we can clearly identify that these two graphs are inverse images of each other. This indicates that with increased hydrocarbon saturation, the water saturation decreases, and vice versa. This shows the zones of less water saturation and high hydrocarbon saturation.

Conclusions
The objective of the current research work was to interpret the subsurface structure and reservoir characterization of Kabirwala area Tola (01), located in Punjab platform, Central Indus Basin, utilizing 2D seismic and well log data. Formation evaluation for hydrocarbon potential using the reservoir properties was performed in this study. The outcomes of the current study are summarized as follows:

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The seismic data interpretation confirms that normal faults with horst and graben structures are favorable for the accumulation of hydrocarbons.

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The high zone present in the northwestern part of the contour maps could be a possible location of hydrocarbon entrapment, which is further confirmed by the presence of the Tola01 well.

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For the marked zone of interest, the average water saturation is 18%, average total porosity is 27.8%, average effective porosity is 8.2%, and net pay thickness is 84.14 m.

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The time section confirms that the formations are shallower in the northwestern direction and deeper along the southeastern direction. The stratigraphic conditions of these Jurassic age formations led to a complete petroleum system in the area. • As a limitation, the current study needs further and suitable calibration with more actual well data to prove reliability and efficiency.

•
In the future, we will implement 3D seismic data interpretation in the proposed field of our research. Similarly, we will also attempt to use the inversion algorithm for further exploration to obtain rich information.