Gas Hydrate Saturation Estimates, Gas Hydrate Occurrence, and Reservoir Characteristics Based on Well Log Data from the Hydrate-01 Stratigraphic Test Well, Alaska North Slope

Haines, Seth S.; Collett, Timothy S.; Yoneda, Jun; Shimoda, Naoyuki; Boswell, Ray; Okinaka, Norihiro

doi:10.1021/acs.energyfuels.1c04100

Cited by 20 publications

(15 citation statements)

References 46 publications

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“…In addition to the acquisition of LWD data, mud logging-acquired drill cuttings samples and gas geochemistry data were collected in both the surface and production hole section of the Hydrate-01 STW for real-time geologic characterization, archival storage of drill cuttings samples, and to obtain cuttings for gas geochemical analysis. Ultimately, the examination of the LWD-acquired logging data confirmed the occurrence of gas hydrate and suitable reservoir conditions for production testing in both Units B and D, thus eliminating the need for contingency wireline logging. ,, …”

Section: Hydrate-01 Logging-while-drilling Operations and Datamentioning

confidence: 80%

“…production hole section was in very good condition resulting in outstanding LWD data quality. The acquisition of a full suite of high-quality MWD/LWD data from the production section of the STW, including gamma-ray, resistivity, acoustic, and nuclear magnetic resonance (NMR) well logs enabled the assessment and confirmation of the occurrence of gas hydrate in the targeted reservoirs within Units B and D (Figures –), achieving one of the primary objectives of the Hydrate-01 STW. ,,, As discussed above in this report, however, it is also important to highlight that the quality of portions of the LWD acquired log data in the in the 12-1/4 in. surface hole of the Hydrate-01 STW was significantly degraded by wellbore enlargements or “washouts” that were attributed to the melting of ice-rich permafrost.…”

Section: Hydrate-01 Logging-while-drilling Operations and Datamentioning

confidence: 97%

“…Ultimately, the examination of the LWD-acquired logging data confirmed the occurrence of gas hydrate and suitable reservoir conditions for production testing in both Units B and D, thus eliminating the need for contingency wireline logging. 14,32,33 The primary well data obtained from the Hydrate-01 STW featured the acquisition of a full suite of Schlumberger LWD and MWD well logs (Table 2). LWD/MWD operations in the 12-1/4 in.…”

Section: Operations and Datamentioning

confidence: 99%

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Planning and Operations of the Hydrate 01 Stratigraphic Test Well, Prudhoe Bay Unit, Alaska North Slope

et al. 2022

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The National Energy Technology Laboratory, the Japan Oil, Gas and Metals National Corporation, and the U.S. Geological Survey are leading an effort to conduct an extended gas hydrate production test in northern Alaska. The proposed production test required the drilling of an initial stratigraphic test well (STW) to confirm the geologic conditions of the proposed test site. This well was completed in January 2019 in cooperation with the Prudhoe Bay Unit Working Interest Owners. The Prudhoe Bay Unit Hydrate-01 STW was spudded on 10-December-2018. Downhole data acquisition was completed on 25-December-2018, and the rig was released on 01-January-2019. The Hydrate-01 STW was drilled in two sections, including the surface hole that was drilled to a depth of 2248 ft measured depth (MD) (685 m MD) and cased, and the production hole section that was drilled to a depth of 3558 ft MD (1084 m MD) and also cased. A thermally chilled mineral-oil-based mud was used in the main (production) hole section of the well to maintain wellbore stability and quality of the wellbore acquired data. The primary wellbore data were acquired using logging-while-drilling tools. A sidewall pressure core system was also deployed to gather grain size and other data needed for the design of the future production test wells. In addition to confirming the geologic conditions at the test site, the Hydrate-01 STW was designed to serve as a monitoring well during future field operations. Therefore, two sets of fiber-optic cables, each including a bundled distributed acoustic sensor (DAS) and a distributed temperature sensor (DTS), were clamped to the outside of the production casing and cemented in place. In March 2019, the project team acquired three-dimensional (3D) DAS vertical seismic profiling data in the Hydrate-01 STW. Temperature surveys were also acquired with the DTS as deployed in the Hydrate-01 STW during the completion of the well and nearly continuously since March-2019.

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Section: Hydrate-01 Logging-while-drilling Operations and Datamentioning

confidence: 80%

Section: Hydrate-01 Logging-while-drilling Operations and Datamentioning

confidence: 97%

Section: Operations and Datamentioning

confidence: 99%

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Planning and Operations of the Hydrate 01 Stratigraphic Test Well, Prudhoe Bay Unit, Alaska North Slope

et al. 2022

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“…Thus, the cylindrical domain was discretized into 627 x 343 = 215,061 gridblocks in (r,z) using the MeshMaker V2.0 package. 44,45 Treating hydrate dissociation as an equilibrium reaction 46 and accounting for the effect of the (generally low, at 0.5%) [17][18][19] salinity on hydrate dissociation resulted in a system of about 860K equations, the number of which dictated the use of the parallel version of the code and the use of high-performance computing resources for the solution of the problem.…”

Section: Domain Discretizationmentioning

confidence: 99%

Numerical Simulations in Support of a Long-Term Test of Gas Production from Hydrate Accumulations on the Alaska North Slope: Reservoir Response to Interruptions of Production (Shut-Ins)

2022

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We investigate by means of numerical simulation a planned year-long field test of depressurization-induced production from a permafrost-associated hydrate reservoir on the Alaska North Slope at the site of the recently-drilled Hydrate-01 Stratigraphic Test Well. The main objective of this study is to assess quantitatively the impact of temporary interruptions (well shutins) on the expected fluid production performance from the B1 Sand of the stratigraphic Unit B during controlled depressurization over different time scales, as well as on other relevant aspects of the system response that have the potential to significantly affect the design of the field test.We consider eight different cases of depressurization, including (a) rapid depressurization over a 60-day period to a terminal bottomhole pressure PW of 2.8 MPa and (b) a slower depressurization rate to a final PW of 0.6 MPa at the end of the year-long production test, in addition to (c) a multi-step depressurization regime and (d) a quasi-linear continuous depressurization strategy. The results of the study indicate that shut-ins obviously reduce gas release and production during and immediately after their occurrence, but their longer-term effects are strongly dependent on the depressurization regime and on the time of observation, covering the entire range of potential outcomes. Shut-ins (a) have a universally strong negative effect when quasi-linear depressurization is involved regardless of the length of the production period, (b) have a strong positive effect in multi-step depressurization schemes that becomes apparent earlier for large initial pressure drops, but (c) can also appear to have practically no effect for slow step-wise depressurization at the end of the year-long production test.Shut-ins lead to a rapid reformation of hydrates, even to the point of disappearance of a free gas phase in the reservoir. Rapid depressurization regimes lead to early maximum rates of hydrate dissociation and gas production, while the maximum rates occur at the end of the production test for the cases of slower depressurization. Shut-ins do not appear to have a significant impact on water production, as the cessation of production is followed by higher rates production when depressurization resumes. Similarly, (a) the fraction of produced CH4 originating from exsolution from the water, (b) the water-to-gas ratio, and (c) the rate of replenishment of produced water by boundary inflows do not appear significantly affected by shut-ins, the effects of which seem to be temporary in the majority of the cases. The study confirmed the superiority of multi-step depressurization methods as the most effective strategies for hydrate dissociation and gas production, and showed that two observation wells (located at distances of 30 m and 50 m from the production well) are appropriately positioned and both able to capture the P, T and SG behavior during the fluid production and shut-ins in any of the eight cases we investigated. over different time scales, as well as on other rel...

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“…International methane hydrate production programs (offshore in Japan, , China, , India, , and South Korea , and onshore in U.S. Alaska North Slope ,− ) have revealed high methane hydrate concentrations in sediments with significant permeabilities required for gas production. , …”

Section: Methane Hydrates As a Massive Bridge Fuel Clean-energy Sourcementioning

confidence: 99%

Energy Transition and Climate Mitigation Require Increased Effort on Methane Hydrate Research

et al. 2022

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Gas Hydrate Saturation Estimates, Gas Hydrate Occurrence, and Reservoir Characteristics Based on Well Log Data from the Hydrate-01 Stratigraphic Test Well, Alaska North Slope

Cited by 20 publications

References 46 publications

Planning and Operations of the Hydrate 01 Stratigraphic Test Well, Prudhoe Bay Unit, Alaska North Slope

Planning and Operations of the Hydrate 01 Stratigraphic Test Well, Prudhoe Bay Unit, Alaska North Slope

Numerical Simulations in Support of a Long-Term Test of Gas Production from Hydrate Accumulations on the Alaska North Slope: Reservoir Response to Interruptions of Production (Shut-Ins)

Energy Transition and Climate Mitigation Require Increased Effort on Methane Hydrate Research

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