Review report: Off-grid wind-hydrogen optimization with wind power uncertainty (DOI: 10.13335/j.1000-3673.pst.2024.1177)

Academic fraud report · Geng Detector

Summary

Verdict: QUESTIONABLE. This review examines a 2024 paper in 电网技术 (Power System Technology) by Qiu Yiwei et al. on a two-layer day-ahead/real-time active power balancing strategy for off-grid wind-storage hydrogen production under wind uncertainty, solved via Itô-process modeling and Gurobi. Three concerns are flagged. (1) Arithmetic inconsistency in Table 4, Scenario I: upper-layer profit 284,835 yuan minus lower-layer control cost 2,882 yuan equals 281,953 yuan, but the paper reports total profit 281,952 yuan—a 1-yuan discrepancy, while Scenario II checks out (386,064 − 1,234 = 384,830). (2) Suspicious uniformity: in Tables 1 and 2, all operating-cost last digits are 4 across confidence levels 68–99%, traced to a fixed wind-power cost of 380,194 yuan combined with 1,950-yuan unit startup costs (ending in 0), implying total wind consumption is held constant regardless of reserve level. (3) Methodological concern: the storage (20 MW·h, 40 MW, i.e., ~2-hour rate) is labeled power-type but behaves like energy-type, and validation uses simulated rather than real Inner Mongolia project data. Confidence is moderate; image reuse could not be assessed (text-only).

Verdict

🟡 QUESTIONABLE — arithmetic error, suspiciously uniform cost digits, and idealized validation assumptions. No direct evidence of fabricated core algorithm, but engineering relevance and data integrity are compromised.

Key findings

Arithmetic error in Table 4 (Scenario I): 284,835 − 2,882 = 281,953, but the paper reports 281,952 (1-yuan shortfall). Scenario II (386,064 − 1,234 = 384,830) is correct.
Suspicious digit uniformity in Tables 1–2: All operating-cost values end in 4 across confidence levels 68%, 75%, 85%, 90%, 95%, 99%. This is explained by a fixed wind cost of 380,194 yuan (last digit 4) and 1,950-yuan startup-cost multiples (last digit 0), meaning total wind energy consumption is constant regardless of reserve level.
Methodological concern (storage characterization): A 20 MW·h / 40 MW battery corresponds to a ~2-hour C-rate, which is energy-type rather than the claimed power-type storage. True power-type storage (supercapacitors, flywheels) typically operates at >10C (<6 minutes).
Validation scope: The case study is constructed from an Inner Mongolia project plan but relies on Itô-process-simulated wind power rather than field measurements; results therefore reflect algorithmic behavior under synthetic conditions.

Evidence highlights

DOI: 10.13335/j.1000-3673.pst.2024.1177
Table 4 (Scenario I): upper-layer profit 284,835; lower-layer control cost 2,882; reported total 281,952; computed total 281,953; Δ = 1 yuan.
Table 4 (Scenario II): 386,064 − 1,234 = 384,830 ✓
Table 1 operating-cost last-digit pattern: 404,294 / 405,544 / 406,744 / 407,244 / 407,494 / 407,744 — all ending in 4.
Table 2: fixed wind cost 380,194 yuan; startup cost 1,950 yuan (×N); startup cost unit ends in 0, propagating last digit 4.
Storage spec: 20 MW·h energy, 40 MW charge/discharge power → ~2-hour rate.

Notes

Image reuse could not be assessed because only textual content was provided (e.g., Figures 5 and 6 not available for pixel comparison).
The 1-yuan error may reflect a typo, but it appears in a tabulated total alongside an otherwise correctly computed row, which weakens the benign-error hypothesis.
The "constant wind consumption" assumption is internally consistent given the model's structure but is unusual for a robust/stochastic comparison across reserve levels; it limits the practical interpretability of the cost trade-off curves.
Confidence: moderate. The findings are consistent with editorial sloppiness and over-idealized benchmarking rather than outright data fabrication; core optimization framework is not directly impeached. Independent verification of Table 4 source files is recommended.