CBG technology and project FAQs.

Biogas is the gas produced by anaerobic digestion. CBG is upgraded and compressed gas meeting the applicable sale specification. Raw-gas volume, methane volume and saleable CBG mass are different quantities.

Microorganisms break down biodegradable organic matter without oxygen through interacting stages of hydrolysis, acid formation, acetogenesis and methane formation. Stable operation depends on keeping these processes in balance.

Hydraulic retention time relates working liquid volume to daily liquid flow. Organic loading rate relates organic input, commonly volatile solids, to working volume and time. Both are needed; neither alone proves a sound digester design.

No. Fibres, moisture, grit, biodegradability, inhibitors and handling properties affect preparation, mixing, retention and loading. The design must follow the selected feedstock and operating regime.

Only within the plant's biological and mechanical capacity. Uncontrolled increases can cause accumulation of acids, mixing difficulties and poorer conversion. Changes need a monitored operating plan.

Total solids identify the dry fraction of a sample; volatile solids identify the organic fraction within it. Multiply wet-feed mass by TS fraction and VS/TS fraction before applying a VS-based methane yield. Keep sample conditions and gas reference units explicit. A wet tonne with more water contains less organic material to convert.

Define the process boundary first. A stream circulating within the same system is not automatically new external throughflow. Fresh feed, dilution, external returns and discharge must be identified consistently, and the working liquid inventory must be established from the operating levels.

Before fixing capacity or making major equipment commitments. It should test the feedstock catchment, site, gas route, utilities, digestate outlet and financial sensitivities.

There is no reliable answer based only on TPD. Feedstock buffers, storage method, process configuration, digestate handling, access and local siting requirements determine the land need.

A proposed location, available land information, preferred feedstocks and your investment objectives are enough to begin. Detailed surveys and technical assumptions can be developed during the assignment.

No. Lenders make their own assessment of the borrower, project, security, equity, approvals and repayment capacity. A DPR must expose the assumptions and risks that support the financing case.

Yes, where electricity savings are relevant. Available area, irradiation, shading, grid interfaces and the hour-by-hour electricity requirement should be considered alongside the plant layout.

Large purchases can occur months before the material is used and gas revenue is earned. The funding schedule needs to include stock purchase, transport, storage losses and inventory finance when they occur. An annual profit estimate can hide a substantial seasonal cash requirement.

Yes. If dependable feed, usable land, gas demand or financing cannot support the initial target, a smaller or phased project may be more practical. The recommendation should follow the evidence and identify which constraint determines the capacity.

Review the currently applicable national and state framework, application windows, project eligibility, sanction conditions and support for related infrastructure. An announcement does not establish a particular project's entitlement.

The Cabinet announced a unified national scheme for CBG. Our dated policy note links to the original announcement. Project-specific benefits should be assessed against the implementing rules and written approvals.

Only if the approved disbursement conditions actually support that treatment. Financial models should separately show sanction, eligible expenditure, claim milestones and receipt timing.

No. Establish product quality, registration or other applicable requirements, buyer demand, transport responsibility and the exact eligibility rules for any assistance. Gross digestate quantity is not equivalent to saleable product.

Not necessarily. Check overlap, double-funding restrictions, eligible cost definitions and the relevant approvals before adding benefits together in the project model.

For fuel procurement discussions, OMC usually means an Oil Marketing Company such as IOCL, BPCL or HPCL. ONGC is a different organisation. Identify the exact proposed buyer and agreement route.

No. Read the document's conditions, validity, milestones and remaining approvals. Confirm the binding purchase terms, delivery point and acceptance obligations in the applicable agreement.

Review quantity, quality, delivery pressure and point, measurement, price basis, deductions, payment, rejected gas, interruption, transport duties and termination conditions with appropriate commercial and legal review.

Compare distance, connection availability, pressure, metering, minimum volumes, fees and utilisation against cascade loading, round-trip time and transport cost. The viable route depends on the project.

No. Conversion requires the specified calorific-value basis, units and contractual measurement conditions. Confirm taxes, delivery costs, deductions and effective applicability before modelling net receipts.

Use the agreed gas inventory and a complete loading, travel, unloading and return cycle. Allow for availability, residual pressure, route constraints and the actual dispatch schedule. Nominal water capacity alone does not establish delivered gas mass or the number of trips a vehicle can complete.

Use the same inlet gas, product specification and operating hours. Compare methane recovery, power, pre-treatment, consumables, uptime, service support and lifecycle cost alongside purchase price.

No. Purity is the methane concentration of the product; recovery is the proportion of inlet methane retained in that product. A high-purity stream can still be produced with significant methane loss.

Calculate the mismatch between continuous production and downstream consumption, including operating windows and credible interruptions. Distinguish nominal volume from usable storage range.

No. Flow depends on the pump curve, pressure or head, fluid properties, speed and the actual system. Slurry solids, fibre and suction conditions also matter.

Measurement is needed to establish quantity, quality and control. The exact instruments, accuracy, calibration and logging arrangement should follow the plant safety design and buyer's acceptance requirements.

Not necessarily. Holder duty follows the cumulative mismatch between hourly production and processing. A shorter upgrading shift needs a buffer, but its usable capacity should be calculated from the schedule and converted to actual holder conditions. Nominal volume and working capacity are different.

CFD can help investigate circulation under a specified tank geometry, slurry model and equipment arrangement. Its value depends on the quality of those assumptions and the question being tested. A flow image without a documented model or acceptance criteria does not prove mixing performance.

Identify land, civil and process packages, utilities, electrical and controls, installation, approvals, logistics, taxes, start-up, financing during construction and working capital. State exclusions rather than comparing an incomplete headline price.

Feedstock properties, retention volume, civil configuration, storage, redundancy, gas delivery and client/EPC boundaries can differ materially. Compare a common design and commercial basis.

Track delivered feedstock, preparation, electricity, labour, maintenance, chemicals, media, laboratory work, gas transport, digestate handling and overheads. Keep financing and depreciation visible in the appropriate financial statements.

Reconcile sampled feed quality, organic input, conservative methane conversion, recovery and operating availability. Separate a laboratory potential from the plant's saleable-gas commitment.

Test feedstock price and availability, gas yield, downtime, energy use, selling terms, construction delays and incentive timing. Include combined downside cases, not only one-variable changes.

The ratio has two inputs: electricity consumption and saleable output. If output falls while consumption stays similar, kWh/kg rises. Examine both the absolute consumption and production before concluding that a machine has become less efficient.

The financial case should show sales and associated treatment, storage, bagging where applicable, handling and delivery costs. Net realisation is the amount remaining within the stated cost boundary. Do not apply a finished-product price to every tonne of untreated slurry.

Record material receipts and feeding, key process readings, gas volume and composition, electricity, downtime, alarms and corrective actions. Use consistent units and calibrated instruments.

No. Evaluate trends in feed, gas, temperature, alkalinity and relevant acid measurements together. A buffered digester may show limited pH change while its condition is deteriorating.

Follow the approved escalation procedure, verify the measurements and review feed changes, process trends, gas losses and equipment availability. Avoid large unassessed loading or dosing changes.

Use approved SOPs, calibrated readings, preventive maintenance and recorded changes. Do not bypass interlocks, conceal abnormal readings, overload the process or enter hazardous areas without the required controls.

Review scheduled work completion, critical defects, repeat failures, downtime causes, spare availability and safety actions. A completed checklist is useful only when it reflects the actual equipment condition.

A repair restores the immediate function. A corrective action addresses the reason a fault occurred or keeps recurring. Both may be necessary, but the maintenance record should distinguish them and define how the lasting improvement will be verified.

Multiple changes can make it difficult to identify what caused the result. A controlled improvement plan should record the starting conditions, authorised changes and the measurement response. Safety and approved operating limits continue to govern every intervention.

No. It estimates methane potential under the test conditions. Storage, preparation, retention, inhibition, mixing and recovery affect the plant's actual result.

Crop plans need evidence on irrigation, harvest schedule, yield variability, transport, storage losses and alternative demand. Leased acreage alone does not confirm usable annual feed.

Its fibres and handling properties require evaluation against the selected process. Removal of contaminants and suitable preparation are needed; the treatment route should be supported by trials or relevant design evidence.

No. Crop condition, chopping, compaction, sealing, drainage and storage management affect preservation. Inspect quality and usable organic content rather than relying only on elapsed days.

No universal percentage is appropriate. Review water balance, salts, ammonia, inhibitors, solids and process requirements before setting a recirculation limit.

No. Moisture, organic content, contamination, transport and preparation affect the usable energy value. Compare the delivered cost per unit of credible methane potential as well as the wet-tonne price, and account for storage and handling losses.

Yes. Methane presents fire and explosion risks; H₂S is toxic, and oxygen-deficient spaces can be fatal. Detection, ventilation, isolation and emergency arrangements need competent design and trained personnel.

Opening a cover does not make it safe. Entry requires the site's authorised confined-space procedure, isolation, atmospheric testing and rescue arrangements. Never attempt an unplanned rescue.

No. Stop and escalate under the approved procedure. Protective systems must be restored and the cause assessed by authorised personnel before the affected operation resumes.

No. Testing, product requirements, storage, nutrient management, buyer suitability and applicable environmental conditions must be established. A disposal route should be defined before plant capacity is finalised.

No. Leaks, unburned residual gas and uncontrolled emissions reduce product recovery and can weaken the environmental benefit. Include gas accounting, leak detection and repair, suitable residual-gas treatment and digestate management in the design and operating plan.

Conventional grid-connected solar generally disconnects during a grid outage. Backup operation requires a separately engineered system with suitable control and protection.

No. Use actual demand timing, generation estimates, available area and the grid/export arrangement. Connected load is not the same as simultaneous demand or daily energy consumption.

Only energy that actually displaces a charge can be valued on that basis. Exported, curtailed or stored energy may have different costs and value. Match generation to hourly demand and verify the applicable grid and export arrangement before calculating savings.