The Middle Ordovician (Middle to Late Cardocian) Hanadir Shale member of the Qasim Formation is a potential shale gas exploration target. This paper quantitatively characterizes the mineralogy of the Hanadir Shale using an applied methodology to better understand the interrelationship between mineralogy and reservoir properties of shale gas formations. A 9-m thick sequence of the Hanadir Shale within the Tabuk quadrangle in northwest Saudi Arabia was investigated using sedimentological, geochemical, and mineralogical analyses. Sequential analyses were performed on shale samples: X-ray diffraction (XRD), X-ray fluorescence (XRF), cations exchange capacity (CEC), and linear swelling meter (LSM). This shale sequence is dominantly comprised of laminated clay-rich shale interbedded with thin siltstone to very fine sandstone beds. It is overlying a 5-m thick bearing with massive-to-low-angle crossbedding in the uppermost intervals of the Sajir member of the Saq Formation and underlying 30-m thick tigillites in the Kahfah member. The XRD results showed the Hanadir Shale is characterized by similar mineralogical composition of different proportions with all the samples containing high silica content (~50%), K-feldspar (~30%), and Na-feldspar (3%). Compared to the bulk mineralogy of the shale gas, clay content in the samples (10 to 20%) is relatively low. The identified clay types include kaolinite, illite, and smectite. Carbonate minerals (calcite and dolomite) also occur as traces (~1%) in all the samples. Swelling tests were performed to understand the swelling properties of the clay content and better understand reservoir properties, performance, and fluid properties in the Qasim Shale's reservoir equivalents. The study contributes to the existing database of shale gas exploration information. Clay mineral distribution patterns and their effects on the reservoir quality of the unconventional shale gas are not well understood; therefore, this study contributes to the understanding of the reservoir behavior of not only the Hanadir Shale but also other regional potential shale formations.

Proppant flowback can cause equipment damage and restrict hydrocarbon production, making it an expensive issue. In response to industry demands for a solution, this paper presents a methodology designed to identify and help prevent flowback issues and to exhibit high cohesive strength to increase the stability of proppant packs. Liquid resin proppant coating applied during pumping operations shows significant conductivity enhancement and fines control in hydraulic fracturing operations, as compared with traditional curable resin-coated proppant (CRCP). The concentration of resin applied follows proven industry standards. Placement technique and concentration of resin can delay the cure time if needed, which enables the proppant pack to consolidate after placement in the fractures. In addition, it enables the proppant to obtain better grain-to-grain contact in the fracture, and capillary action pulls the liquid resin coating to the contact points of the proppant grains. This process provides a highly cohesive, consolidated proppant pack. The liquid resin system was designed to be mixed with the proppant immediately before it is added to the fracturing fluid during pumping operations, to consolidate after it is carried into the fracture. Laboratory analysis demonstrates that the resin will prevent fines from flowing back, and it will remain coated on the proppant in the fracture. During the post-treatment cleanout process, a flowback sample was collected and sent to the laboratory to verify that there was no resin content present. The sample was analyzed using Fourier transform infrared (FTIR) spectroscopy, and the resulting spectra were compared to the original resin chart. No resin was present. To confirm the results, a sample of the resin used on the treatment was mixed and analyzed for comparison in FTIR spectra. This paper describes the methodology to identify the presence of resin during well cleanout and to evaluate the proppant consolidations expected. A new methodology is presented to compare the fluid returned during well cleanup and to evaluate samples in laboratory experiments.

Scale deposition in oil and gas wells has been challenging for many years. Scaling severely decreases flow capacity and hydrocarbon production as a result of reduction in the tubular diameter. Various techniques have been developed and implemented in the field, including mechanical (drilling, milling, and jetting) and chemical solutions, to remove different types of scale. This paper presents a novel laboratory approach to determine an effective mechanical scale-removal material used in jetting tools. This approach thoroughly screens possible scale-removal materials and enabled the identification of a new material that is acid-soluble in nature, water-insoluble, and possesses little/mild strength. These properties ensure the effective removal of various types of scale without damaging the tubulars. A novel laboratory approach was devised to meet the necessary criteria for an effective scale-removal material, which included sphericity and roundness analysis, single-grain crush test, photomicrographs, abrasion test, water solubility, and acid solubility tests. Following the new approach, several potential products were analyzed to determine the best material for scale removal using a jetting tool. The evaluation was performed, focusing on scale removal requirements and cleanout while ensuring tubular protection. The approach in this study was designed while considering the actual well scenario and various types of scale. The variety of materials used had different responses in the laboratory evaluation; the material that best fulfilled the criteria was recommended for scale removal using a jetting tool. The material identified using the new approach effectively removes scale deposits without damaging the tubular. In addition to its non-damaging characteristic with respect to the tubular, the new material is also easily removable after the scale removal treatment. This study proposes a novel laboratory approach and describes the use of this approach to identify new mechanical scale-removal product. The approach was developed for the laboratory evaluation of scale-removal materials blasted through a jetting tool; its use resulted in a cost-effective mechanical scale-removal solution that uses a jetting technique and that is more efficient than the conventional materials currently used.

Halliburton uses the term "local content" to describe programs to develop and use local resources in providing our services in that host country. Local content requirements vary by country, but commonly include providing employment opportunities to local citizens, procurement of goods and services from within the country, manufacturing and value addition through partnerships with and development of local entities, training programs to develop the technical skills of local individuals and businesses, and carry out research and development for finding indigenous alternates of imported materials. In almost all cases, local content requirements are mandated by the laws of the countries where we operate. Adhering to and improving local content is an important part of Halliburton's commitment to support the countries in which it operates and it also brings benefits for both Halliburton and local communities. In this paper, we share a case study of how Halliburton carried out the process of localizing chemical manufacturing in Saudi Arabia, the steps taken, and support extended in developing the local suppliers. Meeting local content requirements requires precise collaboration and communication between regional and country management teams, compliance with host country laws and regulations, adherence to Halliburton company policies, and meeting the quality standards the National Operating Company which is the end user in most cases. The methodology for achieving effective localization results started with setting the right strategy and putting challenging but achievable targets. This localization initiative exemplifies company efforts to create value in every aspect of the company's business through the In-Kingdom Total Value Add (iktva) program mandated by the national operating company in the country. Having a local source of manufacturing and supply chain mitigates any disruptions like the one we saw during COVID 19 whereby the movement across borders was partially closed and supply chain globally was disrupted. Any local souring effectively diminishes the impact of any such disruptions. This initiative considered more than 50 Halliburton commercial chemical products and resulted in more than 10 successful replacements. Halliburton was able to export three products to company's operations outside Saudi Arabia. Partnering with Saudi Aramco, chamber of commerce and local manufacturers and suppliers in this program will drive additional domestic value creation to support a rapidly changing economic environment and foster future prosperity.

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