Abstract: Dagang area is an important occurrence zone for shallow oil sands in the western slope belt of Songliao Basin. The oil sands in this area are characterized by large resource volume, high grade, shallow burial depth, low formation temperature, high oil viscosity, and the presence of water-bearing layers in both the roof and the floor of the ore bed, making extraction extremely challenging. Traditional in-situ steam extraction technology for oil sand bitumen is difficult to apply in Dagang area due to issues such as high energy consumption, high carbon emission, and incompatibility with reservoir characteristics. Microbial cold recovery technology offers advantages including environmental friendliness, low cost, and a wide applicable temperature range, making it a promising new direction for the in-situ green extraction of shallow, low-temperature, high-viscosity oil sands in this region. The Oil and Gas Resources Survey Center of the China Geological Survey drilled one hydrological observation well and five test wells in Dagang area, forming a small well pattern. A microbial degradation agent was obtained through targeted screening, with Pseudomonas as the main functional bacterium. A pretreatment process combining the degradation agent with sulfur-removing and nitrogen-removing functional microorganisms enabled the degradation of crude oil colloids and asphaltene adsorbates under low-temperature conditions. After the implementation of large-aperture, deep-penetration composite perforation operations, as well as oil-based fermentation fluid + nano-microemulsion straight-well huff-and-puff and shut-in treatments, the average injection pressure per well was reduced to 1.0~1.8 MPa. This effectively unblocked the pore seepage channels of the oil sand reservoir and achieved near-wellbore plugging removal. An integrated production process combining oil-water separation, heating, and reinjection functions was established, forming relatively complete technical requirements and process parameters. Through a production test with one injection well and four production wells, 21 tonnes of oil fluid were successfully produced. This approach effectively reduced production costs and energy consumption, compared with straight-well steam thermal recovery under the same conditions, providing references for technical framework and construction methodology for the green in-situ recovery of similar shallow, low-temperature, high-viscosity oil sand mining in China.