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arxiv: 2605.16711 · v1 · pith:JJBVIK47new · submitted 2026-05-15 · ⚛️ physics.geo-ph

Stress state, subsidence, and faulting in the Wilmington Oil Field, California: a multiphase flow-geomechanics modeling assessment (1936-2020)

Llu\'is Sal\'o-Salgado , Josimar A. Silva , Andreas Plesch , Franklin D. Wolfe , John H. Shaw , Ruben Juanes This is my paper

Pith reviewed 2026-05-19 20:25 UTC · model grok-4.3

classification ⚛️ physics.geo-ph
keywords Wilmington Oil Fieldsubsidencestress regimefault stabilitygeomechanics modelingoil productionseismicityreservoir operations
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The pith

Numerical model of Wilmington oil field shows low deviatoric initial stress best matches observed subsidence

A machine-rendered reading of the paper's core claim, the machinery that carries it, and where it could break.

The paper develops a multiphase flow-geomechanics model of the Wilmington Oil Field to examine how nearly a century of oil production and water injection altered the stress state, produced nearly 9 m of subsidence, and contributed to faulting and well shearing. It tests how the uncertain initial stress regime in the shallow crust controls surface deformation and fault stability when the model is calibrated to historical reservoir pressures and displacement records. The central result is that low deviatoric stress throughout the sedimentary section reproduces the data far better than the previously assumed critically stressed reverse-faulting regime, pointing to depth-dependent changes in the stress regime.

Core claim

Model results show that the previously assumed stress regime in the field (reverse faulting) needs to be reassessed—the best match to the ground deformation data is achieved when the sedimentary section is initialized with low deviatoric stress (i.e., not critically stressed). This suggests significant variation in the stress state with depth, including a likely change in the stress regime. DCFF values suggest minor destabilization on reservoir faults and larger changes on sub-horizontal bedding planes; both could explain the faulting that led to sheared wells and seismicity between 1947 and 1961.

What carries the argument

Calibrated multiphase flow-geomechanics numerical model with detailed fault surfaces, well-level production and injection schedules, and elastoplastic constitutive framework used to isolate the effect of initial stress state on subsidence and fault stability

Load-bearing premise

The elastoplastic framework, detailed fault geometry, and calibration to published pressure and displacement data are sufficient to isolate the initial stress state without major interference from unmodeled processes such as chemical compaction.

What would settle it

Direct in-situ stress measurements at several depths in the Wilmington sedimentary section that show either critically stressed reverse faulting throughout or no depth variation in deviatoric stress.

Figures

Figures reproduced from arXiv: 2605.16711 by Andreas Plesch, Franklin D. Wolfe, John H. Shaw, Josimar A. Silva, Llu\'is Sal\'o-Salgado, Ruben Juanes.

Figure 1
Figure 1. Figure 1: Perspective view of the study area (see inset for location) and the subsurface con￾text of the Wilmington field (window cutout). Green color scale and contours: depth of reservoir horizon (California Division of Oil and Gas, 1964, 1992); green well derricks: active well plat￾forms; shaded red and grey: 3D fault surfaces (Plesch et al., 2026); brown color scale: hypocen￾ters colored by year of occurrence (H… view at source ↗
Figure 2
Figure 2. Figure 2: a: Perspective view of total subsidence in the Wilmington field (color contours, 1 m interval, from Mayuga, 1970). White outlines: field boundaries; green well derricks: THUMS oil islands; stippled red line: tip line of blind Wilmington thrust (Wolfe et al., 2019; Plesch et al., 2026); white lines: location of cross-sections; imagery: NAIP (USDA Farm Services Agency). b: cross-section X–X′ (modified from M… view at source ↗
Figure 3
Figure 3. Figure 3: a: Modified Drucker-Prager Cap Model in the p ′ - q plane, where p ′ is the mean effective stress and q is the von Mises stress. The model is defined by a shear failure envelope closed by a cap. The flow potential surface, shown with dashed lines, has a part identical to the cap yield surface (Gc) and another elliptical part in the shear failure region (Gs). b The yield surface shown in the π-plane, define… view at source ↗
Figure 4
Figure 4. Figure 4: Geological model for the Wilmington oil field. (a) View from the top. Colored surface is the top of the Ranger zone (main producing interval). Black contoured lines indicate the location of the total ground subsidence between 1936 to 1955 (Mayuga, 1970); white dots are the well locations. White surfaces are normal faults that were interpreted based on cross-sections found in the literature (Wright, 1991). … view at source ↗
Figure 5
Figure 5. Figure 5: Overview of computational mesh. (a) The Wilmington oil field, located in the cen￾ter of the domain, and regional faults. (b) View showing into the model domain, emphasizing the location of the Wilmington oil field in the center. (c) Embedded faults discretized in the com￾putational mesh. (d) View showing the producing interval (Ranger zone) along with the faults cutting the reservoir. The east-west, north-… view at source ↗
Figure 6
Figure 6. Figure 6: Density (a), dynamic viscosity (b), and two-phase relative permeability curves (c, d) for water, oil, and gas at Wilmington. i.e., no-flow was specified everywhere, but a pore volume multiplier (PVM) was added to all cells in the south-east and south-west boundaries during history matching to rep￾resent formation continuity beyond the domain. Intra-reservoir faults (also referred to as tear or transverse f… view at source ↗
Figure 7
Figure 7. Figure 7: a: Side view of the reservoir simulation domain showing all tear faults. Trans￾missibility multipliers for faults with values different than 0, and the south-west and south-east boundaries, where pore volume multipliers were used, are specified. b: Map view of the reservoir simulation domain, showing cell centroid depths, well locations, and coastline. and 2 strike-slip; and between 2 and 3 reverse faultin… view at source ↗
Figure 8
Figure 8. Figure 8: Initial total stress magnitudes as a function of depth. Note that the overburden stress remains the same across the two plots, but its magnitude relative to the other two prin￾cipal stresses does not. a: Reverse faulting stress regime, with Aϕ from best fit to data in the SCEC Community Stress Model (Hardebeck et al., 2024). b: Heterogeneous strike-slip stress regime, where the sedimentary section has lowe… view at source ↗
Figure 9
Figure 9. Figure 9: Hardening curves obtained with Eq. 20 and the parameter values listed in [PITH_FULL_IMAGE:figures/full_fig_p017_9.png] view at source ↗
Figure 10
Figure 10. Figure 10: a: Quarterly oil production in millions of barrels of oil (MMBO). b: Quarterly water injection in millions of barrels of water (MMBW). c: 98th percentile of the absolute value of pore pressure change between a given time and the pre-production pressures. The percentile was computed using cells above the oil-water contact only. part of field development (1940-1960). During this time, the pore pressure was … view at source ↗
Figure 11
Figure 11. Figure 11: Pressure changes (with respect to pre-production pressures) in the Ranger Fm in (a) 1958, before water injection started; b: 1975, after re-pressurization; c: 1995; and d: 2020. crease in the Ranger zone. This is primarily due to the evolution of σ ′ zz, which registers the largest change, and means that very small adjustments of the cap are necessary (Fig. 12a). As a result, matching the modeled subsiden… view at source ↗
Figure 12
Figure 12. Figure 12: Summary of geomechanical results for the reverse-faulting model (Aϕ = 2.06; see § 3.3.2 and Fig. 8a). a: Stress path (left) and vertical displacement computed at the center of the subsidence bowl. b: Temporal evolution of the horizontal and vertical effective stress components aligned with the grid axes (left) and ratios with their initial values (right). c: Surface vertical displacements, with respect to… view at source ↗
Figure 13
Figure 13. Figure 13: Summary of geomechanical results for the strike-slip model (see § 3.3.2 and Fig. 8b). a: Stress path (left) and vertical displacement computed at the center of the subsi￾dence bowl. b: Temporal evolution of the horizontal and vertical effective stress components aligned with the grid axes (left) and ratios with their initial values (right). c: Surface vertical displacements, with respect to pre-production… view at source ↗
Figure 14
Figure 14. Figure 14: Stress changes (with respect to 1936) mapped on the Wilmington Fault. Left col￾umn: shear stress change; Center column: Effective normal stress change; Right column: DCFF. Top row: 1958; Second row: 1975; Third row: 1990; Bottom row: 2020. Stress changes on the reservoir tear faults are summarized in Fig. 15b, where we show the evolution of mean and 95th percentile of DCFF on four faults in the pore pres￾… view at source ↗
Figure 15
Figure 15. Figure 15: a Location of Tear Faults explored in the reservoir. b: Evolution of average (top) and 95th percentile (bottom) DCFF on TF4, TF9, TF10, and TF11. c: Snapshot of DCFF on TF4 (Cerritos) and TF9 (Allied) in 1960. The maximum DCFF on TF9 is ≈ 8.6 bar. Frame (1952); Kovach (1974) documented damage due to shallow earthquakes at Wilmington between 1947 and 1961, predominantly at a depth of ≈500 m. As discussed i… view at source ↗
Figure 16
Figure 16. Figure 16: Reprint of the striking picture from Frame (1952), showing well damage at ≈ 500 m depth. –25– [PITH_FULL_IMAGE:figures/full_fig_p025_16.png] view at source ↗
Figure 17
Figure 17. Figure 17: a Magnitude of computed surface horizontal displacement (||uh||). A maximum of 4.03 m is in close agreement with ground observations, documenting 3.5 − 4 m (§ 2.2). b: Change in shear stress magnitude (left) and DCFF (right) on the Top Pico surface. c: Change in effective normal stress (left) shear stress magnitude (center) and DCFF (right) on the Top Ranger surface. d Time series of mean and P95 DCFF, an… view at source ↗
read the original abstract

Nearly a century of oil production in the Wilmington Oil Field, Los Angeles Basin, California, has modified the stress state, caused nearly 9 m of ground surface subsidence, and been associated with earthquakes that sheared wells. This offers a unique opportunity to elucidate the processes that govern these phenomena: Since the 1930s, approximately 2.5 billion barrels of oil have been produced, accompanied by water injection volumes roughly an order of magnitude larger. Combined with extensive structural and geophysical constraints, this history allows us to interrogate the long-term geomechanical impacts of reservoir operations. Here, we assess (i) how the initial stress state, typically uncertain in the shallow crust ($<5$ km depth), influences subsidence and uplift, and (ii) how production and injection operations affect fault stability. Our numerical model, calibrated with published measurements of reservoir pressures and surface displacements, incorporates a detailed representation of fault surfaces within and around the field, well-level production and injection schedules, and an elastoplastic constitutive framework. Model results show that the previously assumed stress regime in the field (reverse faulting) needs to be reassessed$\unicode{x2014}$the best match to the ground deformation data is achieved when the sedimentary section is initialized with low deviatoric stress (i.e., not critically stressed). This suggests significant variation in the stress state with depth, including a likely change in the stress regime. DCFF values suggest minor destabilization on reservoir faults and larger changes on sub-horizontal bedding planes; both could explain the faulting that led to sheared wells and seismicity between 1947 and 1961.

Editorial analysis

A structured set of objections, weighed in public.

Desk editor's note, referee report, simulated authors' rebuttal, and a circularity audit. Tearing a paper down is the easy half of reading it; the pith above is the substance, this is the friction.

Referee Report

2 major / 1 minor

Summary. The manuscript develops a coupled multiphase flow-geomechanics model of the Wilmington Oil Field spanning 1936–2020. It incorporates well-level production/injection schedules, a detailed fault network, and an elastoplastic constitutive model, then calibrates to published reservoir pressure and surface displacement records. The central result is that initializing the sedimentary section with low deviatoric stress (rather than a critically stressed reverse-faulting regime) yields the best match to observed ground deformation; this leads the authors to conclude that the stress regime must be reassessed and that significant depth-dependent variation, including a regime change, is likely. DCFF calculations are used to link the stress evolution to observed well shearing and seismicity.

Significance. If the finding that low deviatoric stress provides a distinctly superior fit survives further scrutiny, the work would be significant for reservoir geomechanics. It supplies a long-term, data-rich case study of how decades of production and injection modify shallow-crustal stress, subsidence, and fault stability. The result challenges conventional assumptions about reverse faulting in the Los Angeles Basin and offers a concrete example of how initial-stress uncertainty propagates into predictions of induced deformation and seismicity, with direct relevance to subsidence management and well-integrity assessment in mature fields.

major comments (2)
  1. [Calibration and results sections] The central claim—that low deviatoric stress initialization is required to match the deformation data—rests on the calibration procedure. The abstract states that the model is calibrated to pressure and displacement data, yet provides no description of a systematic exploration (Latin-hypercube sampling, MCMC, or equivalent) of the joint parameter space that includes Young's modulus, Poisson's ratio, plastic hardening parameters, fault friction/cohesion, and fault discretization. Without such an analysis it remains possible that compensatory adjustments in these other constitutive and geometric parameters could produce comparable misfits under a critically stressed reverse-faulting initialization, undermining uniqueness of the stress-regime conclusion.
  2. [Model description and discussion] The elastoplastic framework and fault geometry are asserted to isolate the effect of the initial stress tensor. However, the manuscript does not quantify the potential contribution of unmodeled processes (chemical compaction, incomplete representation of sub-seismic faults, or time-dependent creep) to the observed subsidence. Because these processes could alter the stress path and surface displacement independently of the initial deviatoric stress, their omission constitutes a load-bearing assumption for the claim that the stress regime must be reassessed.
minor comments (1)
  1. The abstract refers to 'DCFF values' without defining the sign convention or the reference stress state used for the change calculation; a brief clarification in the methods would improve reproducibility.

Simulated Author's Rebuttal

2 responses · 0 unresolved

We thank the referee for the constructive and detailed review. We respond to each major comment below, proposing targeted revisions to address the concerns while preserving the integrity of our analysis.

read point-by-point responses

  1. Referee: [Calibration and results sections] The central claim—that low deviatoric stress initialization is required to match the deformation data—rests on the calibration procedure. The abstract states that the model is calibrated to pressure and displacement data, yet provides no description of a systematic exploration (Latin-hypercube sampling, MCMC, or equivalent) of the joint parameter space that includes Young's modulus, Poisson's ratio, plastic hardening parameters, fault friction/cohesion, and fault discretization. Without such an analysis it remains possible that compensatory adjustments in these other constitutive and geometric parameters could produce comparable misfits under a critically stressed reverse-faulting initialization, undermining uniqueness of the stress-regime conclusion.

    Authors: We agree that the manuscript would benefit from a clearer description of the calibration approach and additional sensitivity testing to support the uniqueness of the initial-stress conclusion. Other parameters were constrained using independent data (well logs, core measurements, and prior geomechanical studies of the Wilmington field) while the initial stress tensor was systematically varied. In revision we will add a sensitivity-analysis subsection that reports results for variations in Young's modulus, Poisson's ratio, and fault friction/cohesion within literature-derived ranges. These tests confirm that the low-deviatoric-stress initialization remains the best fit. A full joint MCMC exploration is computationally prohibitive for the 84-year, high-resolution model, but the proposed additions will strengthen the robustness argument. revision: yes

  2. Referee: [Model description and discussion] The elastoplastic framework and fault geometry are asserted to isolate the effect of the initial stress tensor. However, the manuscript does not quantify the potential contribution of unmodeled processes (chemical compaction, incomplete representation of sub-seismic faults, or time-dependent creep) to the observed subsidence. Because these processes could alter the stress path and surface displacement independently of the initial deviatoric stress, their omission constitutes a load-bearing assumption for the claim that the stress regime must be reassessed.

    Authors: We acknowledge that chemical compaction, creep, and sub-seismic faults are not explicitly included and could affect subsidence. The elastoplastic model nevertheless reproduces the observed pressure and displacement records over eight decades. In the revised Discussion we will add an explicit limitations paragraph that cites literature estimates for chemical-compaction rates in analogous basins and explains why these contributions are expected to be secondary relative to the poroelastic and plastic effects already captured. We will also note that the fault network is based on all available seismic and well data; any unresolved sub-seismic features would not alter the comparative outcome between the tested initial-stress states. revision: yes

Circularity Check

0 steps flagged

No significant circularity; calibration to external published data yields independent assessment of initial stress

full rationale

The paper sets up an elastoplastic geomechanical model with detailed faults and well schedules, then calibrates it against independent published reservoir pressure and surface displacement records. It compares outcomes across different initial stress states and reports that low deviatoric stress produces the best match to those external observations. This is a standard forward-modeling exercise against benchmarks; the result does not reduce by construction to a fitted parameter renamed as a prediction, nor does it rely on self-citation, uniqueness theorems, or ansatz smuggling. The derivation chain remains self-contained because the constraining data lie outside the model assumptions.

Axiom & Free-Parameter Ledger

1 free parameters · 2 axioms · 0 invented entities

The central claim rests on standard geomechanical assumptions and calibration to historical observations; no new physical entities are introduced.

free parameters (1)
  • Initial deviatoric stress magnitude and orientation
    Tested across different regimes to identify the best match to deformation data
axioms (2)
  • domain assumption Elastoplastic constitutive model adequately captures rock deformation under changing reservoir pressures
    Invoked as the mechanical framework for the entire simulation
  • domain assumption Published reservoir pressure and surface displacement records are accurate and representative
    Used for model calibration

pith-pipeline@v0.9.0 · 5867 in / 1492 out tokens · 48105 ms · 2026-05-19T20:25:58.239557+00:00 · methodology

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Lean theorems connected to this paper

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  • IndisputableMonolith/Cost/FunctionalEquation.lean washburn_uniqueness_aczel unclear
    ?
    unclear

    Relation between the paper passage and the cited Recognition theorem.

    Our numerical model, calibrated with published measurements of reservoir pressures and surface displacements, incorporates a detailed representation of fault surfaces within and around the field, well-level production and injection schedules, and an elastoplastic constitutive framework.

  • IndisputableMonolith/Foundation/RealityFromDistinction.lean reality_from_one_distinction unclear
    ?
    unclear

    Relation between the paper passage and the cited Recognition theorem.

    Model results show that the previously assumed stress regime in the field (reverse faulting) needs to be reassessed—the best match to the ground deformation data is achieved when the sedimentary section is initialized with low deviatoric stress

What do these tags mean?
matches
The paper's claim is directly supported by a theorem in the formal canon.
supports
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extends
The paper goes beyond the formal theorem; the theorem is a base layer rather than the whole result.
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The paper appears to rely on the theorem as machinery.
contradicts
The paper's claim conflicts with a theorem or certificate in the canon.
unclear
Pith found a possible connection, but the passage is too broad, indirect, or ambiguous to say the theorem truly supports the claim.

Reference graph

Works this paper leans on

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