Genesis and distribution of hydrogen sulfide in deep heavy oil of the Halahatang area in the Tarim Basin, China

Zhu, Guangyou; Liu, Xingwang; Yang, Haijun; Jin, Sheng; Zhu, Yongfa; Wang, Yu; Sun, Chunwei

doi:10.1016/j.jnggs.2017.03.004

Cited by 26 publications

(23 citation statements)

References 34 publications

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“…A comparison with a representative burial history curve for the study area indicates that Middle Ordovician strata attained those depths around the end of the Ordovician (Figure 13). The lack of primary oil inclusions in Cc2 or earlier cements agrees with this timing, preceding the first stage of hydrocarbon generation in the Silurian [1,61]. It is likely that similar fluids that caused stage 1 dissolution continued to cause corrosion of carbonates at this stage.…”

Section: Stagesupporting

confidence: 68%

“…Oil presence is further supported by bitumen in group 3 fractures and vugs. The first oil accumulation in the study area, derived from Cambrian source rocks [90], dates to the Late Caledonian-Early Hercynian period [1,61]. This timing of oil generation and inferred depth for Cc3 cements is compatible with the formation and partial cementation of group 3 features in the Silurian (see Ukar et al [93]).…”

Section: Stagementioning

confidence: 73%

“…Heavy crude oil in the study area is rich in H 2 S, and sulfur content may be as high as 2% [63]. A rise in the temperature of the reservoir caused by burial would trigger thermal decomposition of sulfur compounds to produce more H 2 S [1]. Sulfur-rich oil can mix with water to create H 2 SO 4 in a process similar to that which created Carlsbad Caverns in the Guadalupe Mountains (Texas, USA) [97].…”

Section: Stagementioning

confidence: 99%

“…Giant volumes of oil and gas are contained in Ordovician carbonate rocks of the Tarim Basin, NW China, especially in the Tabei Uplift, where proven oil/gas reserves surpass 3 billion tonnes of oil-equivalent [1]. Well drilling responses such as bit drops and mud losses indicate that high-porosity and high-permeability zones, including large (>10 m) cavities, are present in deeply buried (>6000 m) reservoirs [2][3][4][5].…”

Section: Introductionmentioning

confidence: 99%

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Fracture, Dissolution, and Cementation Events in Ordovician Carbonate Reservoirs, Tarim Basin, NW China

et al. 2020

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Ordovician carbonate rocks of the Yijianfang Formation in the Tabei Uplift, Tarim Basin, contain deeply buried (>6000 m), highly productive oil and gas reservoirs associated with large cavities (>10 m). Previous workers inferred that large cavities are paleocaves (paleokarst) formed near the surface and subsequently buried. Alternately, caves may have formed by dissolution at depth along faults. Using 227 samples from 16 cores, we document textures and cement compositions bearing on cavity histories with petrographic, high-resolution scanning electron microscopy (SEM), isotopic, and fluid inclusion microthermometric observations. Results show that dissolution occurred at depth and was caused by (1) acidic fluids derived from Middle-Late Silurian and/or Devonian-Permian hydrocarbon generation and maturation, (2) high-temperature fluids, of which some were associated with Late Permian igneous activity, and (3) Mg-rich fluids that accompanied Jurassic-Cretaceous deformation and the formation of partially open fractures and stylobreccias (fault breccias). The relative paragenetic sequence of the structure-related diagenesis suggests seven stages of fracturing, dissolution, and cementation. Mottle fabrics in the Yijianfang Formation contain argillaceous carbonate-rich silt and are bioturbation features formed within the marine environment. Those mottled fabrics differ from clearly karstic features in the overlying Lianglitage Formation, which formed by near-surface dissolution and subsequent infilling of cavities by allochthonous sediment. Mottle fabrics are crosscut by compacted fractures filled with phreatic-vadose marine cements and followed by subsequent generations of cement-filled fractures and vugs indicating that some fractures and vugs became cement filled prior to later dissolution events. Calcite cements in fractures and vugs show progressively depleted values of δ18O documenting cement precipitation within the shallow (~220 m), intermediate (~625 m), and deep (~2000 m) diagenetic environments. Deep (mesogenetic) dissolution associated with fractures is therefore the principal source of the high porosity-permeability in the reservoir, consistent with other pieces of evidence for cavities localized near faults.

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Section: Stagesupporting

confidence: 68%

Section: Stagementioning

confidence: 73%

Section: Stagementioning

confidence: 99%

Section: Introductionmentioning

confidence: 99%

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Fracture, Dissolution, and Cementation Events in Ordovician Carbonate Reservoirs, Tarim Basin, NW China

et al. 2020

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“…H 2 S can be the dominant gas in hot (>100°C) carbonate petroleum reservoirs [1] [2][3] [4]. Its abundance in reservoirs is essentially linked to Thermochemical Sulfate Reduction (TSR) which is the reaction of hydrocarbons with sulfate in formation waters within rock strata (e.g.…”

Section: Introductionmentioning

confidence: 99%

Influence of H2S on the thermal cracking of alkylbenzenes at high pressure (70 MPa) and moderate temperature (583–623 K)

Burklé-Vitzthum

Guerra

Lorgeoux

et al. 2019

Journal of Analytical and Applied Pyrolysis

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Preventing sour gas kicks during workover of natural gas wells from deep carbonate reservoirs with anti‐hydrogen sulfide fuzzy‐ball kill fluid

Yan

Okere

Zeng

et al. 2022

Energy Science & Engineering

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Workover of natural gas wells in deep carbonate gas reservoirs (DCRs) is facing multiple challenges such as fluid leakage, high temperature, and hydrogen sulfide (H2S) gas kick. Hence, well‐killing fluids with satisfactory plugging ability, high‐temperature tolerance, and anti‐H2S ability are necessary. In this study, we developed a multifunctional anti‐hydrogen sulfide fuzzy‐ball kill fluid (AFKF) for preventing sour gas kicks in DCRs. The performance of the AFKF was optimized and analyzed via experiments and verified through a case study application. The results showed that the fuzzy‐ball structures in the AFKFs demonstrated good stability under extreme H2S aging. The rate of change of certain critical rheological parameters such as apparent viscosity, dynamic plastic ratio, and density of AFKFs before and after hot rolling were no more than 5%. After plugging the fractures with the AFKFs at temperatures between 110°C and 150°C, the inlet driving pressure of the fractures increased from 20.73°C to 21.07 MPa, and no fluid loss was observed at the core outlet after a secondary displacement of formation water. The permeability recovery rate was greater than 90%. Application of AFKF in well DW‐2 showed that the shut‐in pressure rose to 24.6 MPa with no trace of H2S gas at the wellhead after 4 days. The investigation of the H2S mitigation mechanisms revealed that the plugging of the seepage channels by AFKFs forms interconnected bonds that improve the mechanical properties of the reservoir. Additionally, AFKFs absorb H2S gases by protonation and dissociation reactions which convert the hazardous gas into an aqueous solution of sulfide ions (S2−). The proposed AFKF has proven to be effective means of mitigating H2S in DCRs, and minimize the negative impacts of environmental polution, health risks, and equipment corrosion.

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Genesis and distribution of hydrogen sulfide in deep heavy oil of the Halahatang area in the Tarim Basin, China

Cited by 26 publications

References 34 publications

Fracture, Dissolution, and Cementation Events in Ordovician Carbonate Reservoirs, Tarim Basin, NW China

Fracture, Dissolution, and Cementation Events in Ordovician Carbonate Reservoirs, Tarim Basin, NW China

Influence of H2S on the thermal cracking of alkylbenzenes at high pressure (70 MPa) and moderate temperature (583–623 K)

Preventing sour gas kicks during workover of natural gas wells from deep carbonate reservoirs with anti‐hydrogen sulfide fuzzy‐ball kill fluid

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