In terms of Rule 65 of Public Procurement Rules, 2026, a Grievance Redressal Committee (GRC) is notified for the subject procurement and the notification copy is available on the procuring agency’s website and on Authority’s website at (www.ppra.org.pk).
Private Power & Infrastructure Board (PPIB) (Ministry of Energy (Power Division)), Deputy Director
2nd Floor, OPF Building, Sector G-5/2, Islambad
+92-320-326-1332
haseeb.nawaz@ppib.gov.pk
Sections of Prequalifica¬tion Documents
The following specific data for the Prequalification of Applicants shall complement, supplement, or amend the provisions in the Instructions to Applicants (ITA). Whenever there is a conflict, the provisions herein shall prevail over those in ITA.
PDS Clause Number
ITA Number
Amendments of, and Supplements to, Clauses in the Instructions to Applicants
PDS Clause Number 1
ITA Number 1.1
Identification Number of the Invitation for Prequalification: P171330
The Procuring Agency is: Private Power & Infrastructure Board (PPIB) (Ministry of Energy (Power Division))
List of Service Contracts:
See section services and Lots
PDS Clause Number 2
ITA Number 2.1
The name of Procuring Agency is: Private Power & Infrastructure Board (PPIB) (Ministry of Energy (Power Division))
The name of Project / Procurement is: Expression of Interest (EOI) for Third Party Validation (TPV) Services for Solar Works of 100 MW Distributed Photovoltaic Solar Power Plants in Gilgit-Baltistan
PDS Clause Number 3
ITA Number 4.2
Maximum number of members in a Joint Venture (JV): 3
PDS Clause Number 4
ITA Number 4.5
A list of debarred firms and individuals is available on PPRA website: https://ppra.gov.pk
PDS Clause Number 5
ITA Number 7.1
For clarification, the Applicant shall seek clarifications through: EPADS v2.0
PDS Clause Number 6
ITA Number 7.1 & 8.2
Information related to Prequalification shall be published on: EPADS v2.0
PDS Clause Number 7
ITA Number 7.2
Pre-Application Meeting: Clarification Date: Tuesday, November 24, 2026
PDS Clause Number 8
ITA Number 10.1
This Prequalification Document has been issued in the language: English
PDS Clause Number 9
ITA Number 11.1(d)
Additional documents to be submitted through EPADS v2.0:
PDS Clause Number 10
ITA Number 14.2
Source for determining exchange rates: Not Applicable
PDS Clause Number 11
ITA Number 16.1
Deadline for Application Submission:
Day: Friday
Date: Friday, November 27, 2026
Time: 10:30 AM
PDS Clause Number 12
ITA Number 17.1
Opening of Applications shall be conducted through: EPADS v2.0
Day: Friday
Date: Friday, November 27, 2026
Time: 11:00 AM
Virtual participation link: https://vendors.epads.gov.pk/
PDS Clause Number 13
ITA Number 21.1
Margin of Domestic Preference: Not Applicable
(Applicable only if authorized in Procurement Plan)
PDS Clause Number 14
ITA Number 29.1
Prequalification-related complaints / grievances shall be submitted in writing through: EPADS v2.0
A complaint may challenge:
All Active Taxpayers shall be eligible to participate in the procurement process, unless expressly excluded or otherwise restricted under the Eligibility Criteria specified by the Procuring Agency.
| Required Registration |
|---|
|
None |
| Eligibility Criteria | Document |
|---|---|
| Applicants shall meet all applicable requirements under Section 5 of the attached detailed EOI. Assessment shall be pass/fail, and all qualifying applicants shall be shortlisted. Read these documents with the attached “Amendment to Prequalification Data Sheet—Document Precedence.” In case of conflict, the detailed EOI shall prevail over the EPADS-generated provisions as specified in that amendment. Applicable laws, rules and regulations shall prevail over both documents. | No |
| 1. Legal Registration and Eligibility The single firm and every Joint Venture (JV) member shall be legally constituted and have the capacity to enter into a contract. Provide incorporation/registration documents and satisfy applicable eligibility requirements concerning solvency, convictions, debarment and prohibited practices. Disclose relevant proceedings, restrictions and sanctions. | Yes |
| 2. PEC Registration: Each Pakistani firm/JV member must hold valid PEC consulting registration. Foreign firms must join a PEC-registered Pakistani firm in a JV under E2 and PEC rules. Provide home-country registration, JV details and PEC pre-registration status, with undertakings to obtain required PEC Forms 4B/4C registrations before RFP proposal submission. Registrations mandatory at EOI stage must be provided; undertakings cannot replace them. | Yes |
| 3. Tax Registration Each Pakistani firm/JV member shall provide valid FBR/NTN registration, active taxpayer evidence and applicable service-tax registrations. Foreign firms shall provide home-country tax registration/status and meet Pakistani tax requirements applicable to their status and activities. Any claimed non-applicability shall be supported by its legal basis and evidence. | Yes |
| 4. Authorized Application and JV Arrangement The application shall be signed by an authorized representative, with supporting authorization. A JV shall comprise no more than three member firms. Identify its lead member, participation shares and responsibilities. Provide an executed JV agreement or letter of intent signed by all members, together with member authorizations. Each firm may participate in only one application, individually or as a JV member. | Yes |
| 5. Independence and Integrity Applicants shall have no disqualifying conflict of interest. They shall not independently validate their own work, an affiliate's work or work in which they have a conflicting financial or professional interest. The single firm and every JV member shall submit separate conflict-of-interest and eligibility/debarment/integrity declarations in Forms G and H. Disclose relevant affiliations, project engagements and sanctions. | Yes |
Quality Based Selection (QBS)
Weightage (Without Financial Criteria)
| Technical Evaluation % |
|---|
| 100 |
| Technical Marks | 100 | |
|---|---|---|
| Passing Marks | 100 | |
| Q1 General experience | ||
| Applies to: Single firm or JV lead member alone. At least ten years of general engineering/technical consulting experience as at the deadline. Incorporation alone does not establish consulting experience. Evidence: Form D with dated assignment evidence spanning the required period, contracts/completion certificates or client confirmations; Form B incorporation details. (Quantitative)(Doc Required) | 15 | |
| Q2 Solar PV Experience | ||
| Applies to: Single firm or JV members collectively. Consulting experience on Solar PV projects with cumulative capacity of at least 250 MWp commissioned within the ten years preceding the deadline. Evidence: Form E project schedule and project sheets; capacity, commissioning date, actual consulting role and documentary evidence for each claimed project. (Quantitative)(Doc Required) | 15 | |
| Q3 BESS Experience | ||
| Applies to: Single firm or JV members collectively. Consulting experience on BESS projects with cumulative energy capacity of at least 25 MWh commissioned within the ten years preceding the deadline. Evidence: Form E project schedule and project sheets; energy capacity, commissioning date, actual consulting role and documentary evidence. (Quantitative)(Doc Required) | 15 | |
| Q4 Similar completed assignments | ||
| Applies to: Single firm or JV members collectively. At least three successfully completed similar assignments within the ten years preceding the deadline involving Solar PV, BESS or comparable electrical infrastructure, comprising Independent Engineer, Owner’s Engineer, Lender’s Engineer, Technical Due Diligence, Technical Verification, TPV or Construction Monitoring services. Evidence: Form E, identifying the three or more assignments relied upon; client completion/acceptance evidence, contract summary and contactable client references.. (Quantitative)(Doc Required) | 15 | |
| Q5 Multidisciplinary capability | ||
| Applies to: Single firm or JV collectively. Demonstrate access to the ten disciplines listed in Section 4.12, through employees or an identified panel of associates, with qualifications and relevant experience stated. Detailed RFP expert scoring and exclusive deployment commitments are not applied at EOI stage. Evidence: Form F capability matrix covering all ten roles, brief profiles and evidence of employment or written consent to inclusion in the panel. Applicant’s signed resource undertaking in Form A. (Qualitative)(Doc Required) | 15 | |
| Q6 Financial capacity | ||
| Applies to: Single firm or JV members collectively. Average annual turnover of at least PKR 100 million or equivalent during the last three financial years, and positive net worth in each of those years. For a JV, combine member figures for each relevant year, eliminate double counting, and then calculate the three-year average annual turnover; the combined net worth must be positive in each year. No separate minimum financial share is imposed on a member. Evidence: Form I; audited financial statements by UDIN where applicable in Pakistan, or equivalent verifiable audit evidence for foreign firms for each of the last three financial years for the single firm and every JV member, with reconciliation of the combined figures and currency conversions. (Quantitative)(Doc Required) | 10 | |
| Q7 Solar electrical equipment and control interfaces | ||
| Applies to: Single firm or JV members collectively. Demonstrated engineering review, supervision or independent verification experience covering MV/LV equipment, controls and RTU interfaces relevant to solar EPC works. Equipment supply alone is insufficient. Evidence: Form E project sheets identifying the relevant equipment/interfaces, consulting role and supporting contract/client evidence. The same assignments may support Q2–Q4 and Q7 where each requirement is evidenced. (Qualitative)(Doc Required) | 15 | |
Positions Without Lots :
Position: THIRD PARTY VALIDATION (TPV) SERVICES FOR SOLAR WORKS OF 100 MW DISTRIBUTED PHOTOVOLTAIC SOLAR POWER PLANTS IN GILGIT-BALTISTAN
Specifications / Requirements:
1.   Scope and role: Independently verify solar works for the 100 MWp GB DPV Project: about 18.15 MWp rooftop PV with 11.1 MWh BESS at 499 buildings, and 82 MWp utility PV with 55 MWh BESS at four sites. Cover solar EPC works, approved changes and plant-level C&C/SCADA. Exclude non-solar and project-wide control-centre/EMS works except solar interfaces. TPV shall not replace Client/NESPAK approvals, supervision, contract management or payment certification.
2.   Duration: Follow the Data Sheet and project schedules. Complete each site's checks, tests and reports by its COD, and final reporting and digital handover by the last solar COD. Exclude post-COD O&M, monitoring and defect inspections. Hand over later tests and warranty matters to Client/NESPAK.
3.   Procurement and document review: Review both components RFPs, specifications, criteria, amendments, evaluations, approvals, awards, contracts and re-tendering under applicable rules and transition provisions. Review Rooftop Lots I-III and design approvals within 30 days; submit pending Lot III award findings before award consideration. Review the utility RFP before issue and within 30 days, and later procurement stages normally within seven working days of complete records. Review complete technical submissions through NESPAK within three working days, before Client approval. Keep a contract/design compliance record.
4.   Milestones and payments: Verify every milestone and related payment through COD, including quantities, quality, claims, changes and time extensions. Review every site's records. Check past payments and identify unsupported, duplicate or excessive amounts. Provide an initial payment register with inception reporting and opening reconciliation within 30 days. Identify missing documents within two working days and report findings within seven working days of complete records. Do not recommend unsupported acceptance or payment.
5.   Site coverage: Visit every rooftop site before COD to check location, PV/BESS capacities, main equipment, completeness, visible defects and safety. Use checklists and geo-tagged photos. Check at least 20% of distinct sites in each lot in detail, rounded up. Select sites independently using a Client-approved mix of representative random and higher-risk sampling. Start during installation; phase checks across work/payment stages. Use NESPAK records with independent evidence. Repeat visits do not count as extra sites. Expand checks for material discrepancies, safety risks, recurring defects or unreliable evidence, up to all affected sites. The RFP shall set extra-inspection instructions and rates. Fully cover all four utility sites. Separate basic and detailed checks; follow approved test sampling.
6.   Technical checks: Check PV identity, ratings, serial records, certificates, warranties, origin, condition, layouts and strings; structures, foundations, anchors, bolt tightness and corrosion protection; inverters, protection and anti-islanding; cables, switchgear, meters, earthing and lightning protection. Check BESS chemistry, capacity, BMS/PCS, SOC, alarms, temperature control, fire protection and shutdown against approved designs. At utility sites, also check civil works, transformers, solar HV/switchyard equipment, plant controls and grid connections. Conduct monthly drone surveys during construction and a commissioning survey, subject to permissions or approved alternatives.
7.   Tests and performance: Witness required FAT/SAT, commissioning, grid-code and COD tests covering PV capacity, yield, PR and availability; BESS capacity, RTE, SOC and SOH; and SCADA data, alarms and communications. Verify the ten-day utility performance run where required by contract. Review records of earlier FAT. FAT professional time is included; EPC travel/lodging costs apply only as contracted. Record results, calibration evidence and limitations. Use thermal imaging and required or duly instructed targeted EL tests. Do not add contractor obligations retrospectively.
8.   Reports and resources: Submit inception methodology within 15 days; set up DIMS/GIS within 30 days and enter initial data within 60 days. Submit monthly reports within ten days of month-end, quarterly audits, test reports within five working days and final COD findings. Keep asset, photo, payment and NCR records with Client access/backups. Report critical risks immediately; issue Critical NCRs within 48 hours and Major NCRs within five working days. Verify closure before related recommendations. Hand over minor open items without relaxing acceptance requirements. Provide the ten specified disciplines, inspectors, calibrated equipment, transport and digital tools. Initial deadlines run from commencement; days are calendar unless stated.
1.   Project and purpose: Independently verify solar works under the 100 MWp DPV Project in Gilgit-Baltistan: about 18.15 MWp rooftop PV with 11.1 MWh Battery Energy Storage Systems (BESS) at 499 public buildings and 82 MWp utility PV with 55 MWh BESS at four sites.
Capacities and site numbers are planning figures. Cover the approved solar facilities, signed EPC packages and approved changes. Check procurement, designs, equipment, installation, tests and payments against contracts and approved requirements, and provide evidence-based findings. The RFP shall identify the current site/lot schedule.
2.   Role and limits of the assignment: Remain independent of EPC contractors, suppliers, manufacturers, NESPAK and other implementing parties. Cover PV, BESS, associated solar civil/electrical works and plant-level Control and Communication/SCADA.
Exclude non-solar and project-wide control-centre/EMS works except solar integration interfaces. Limit HV, switchyard and overhead-line checks to solar EPC packages and these interfaces.
Do not prepare detailed designs, provide routine supervision, approve drawings/materials, administer EPC contracts or certify payments. These duties remain with NESPAK/Engineer/Client. TPV records do not replace contractual certificates or reduce contractor responsibilities.
3.   Assignment period and COD boundary: Follow the Data Sheet and project schedules. The stated completion baseline is 31 December 2028. Complete each site's inspections, tests, reports and handover by its Commercial Operation Date (COD), and consolidated reporting/digital handover by the last solar COD. For delayed COD, an extension of up to six months may be approved under the RFP contract arrangements solely to complete services through revised COD.
Exclude post-COD O&M supervision, performance monitoring and defects-liability inspections. Operational/performance checks refer to commissioning/COD tests; review warranties as documents only. Hand over later tests/warranty obligations to Client/NESPAK without extending TPV services.
4.   Procurement and RFP review: Review procurement for both solar components, including completed stages, cancellations and re-tendering. Check RFPs, specifications, eligibility/qualification and evaluation criteria, clarifications, amendments, evaluations, approvals, awards and EPC contracts. Apply rules governing each procurement at initiation, including transition provisions.
Review Rooftop Lots I-III procurement, evaluations, awards and design approvals within 30 days of commencement. Give separate lot-wise findings/actions. Where Lot III award is pending, submit findings before award consideration within the same period.
Review the utility RFP for all four sites before issue and within 30 days. Check technical/procurement requirements, recommend amendments and record Client/NESPAK responses and closure. Review later procurement stages before decisions, normally within seven working days of complete records. Review completed stages retrospectively and state limitations.
5.   Designs and project documents: Review contracts/amendments, designs/drawings, material submissions, specifications, inspection/test plans, FAT/SAT/commissioning records, measurements, payments, variations/claims, as-built drawings, O&M manuals and warranties.
Review existing rooftop designs, material submissions and approvals within 30 days. Comment on later complete submissions through NESPAK within three working days, before Client approval. Identify missing information promptly.
Keep a compliance matrix linking contract/design/specification/standard requirements to checks, evidence, results and outstanding actions. Report gaps and departures from approved requirements.
Acceptance criteria shall be based on the EPC contracts, approved designs and applicable mandatory standards. Industry guidance may support advice but shall not create new contractor obligations retrospectively.
6.   Milestones, payments, variations and claims: Verify every milestone/payment through COD against quantities, quality, delivery, installation, inspection and test evidence. Review every rooftop site's records, including NESPAK records. Physical sampling shall not limit document/payment review.
Review variations, costs, claims and time extensions before approval/payment. Identify unsupported or duplicate amounts, contract departures and risks. Decisions remain with the authorized Engineer/Client.
Reconcile past payments against certificates, invoices, quantities, delivery/test records, photographs, site evidence and required milestones. Keep a register of verified, partly supported, unsupported, duplicate or potentially excessive amounts and recommended action.
Provide an initial register with inception reporting and opening reconciliation within 30 days. Update through COD as records arrive. Missing evidence does not prove satisfactory work.
For new payment submissions, identify missing documents within two working days and provide findings within seven working days of receiving complete records. Target three working days for urgent, fully documented cases. Plan final submissions and reviews to finish by COD.
7.   Verification approach and site coverage: Prepare a Client-approved plan for document review, visits, measurements, functional checks and test witnessing, with sampling, acceptance criteria, specialist inputs and reporting. Use checklists and geo-tagged evidence.
Basic checks at every rooftop site: Visit every rooftop site before COD. Confirm building/location, installation, PV/BESS capacities, main equipment and completeness against approved records. Record visible defects and safety concerns using checklists/photos. Do not present basic checks as detailed testing or full compliance certification.
Detailed rooftop checks: Carry out detailed technical verification at a minimum of 20% of distinct sites in each lot, rounded up to the next whole site. Select sites independently under a Client-approved method combining representative random selection with selection of higher-risk sites. Cover different locations, contractors/installation teams, system capacities and PV/BESS arrangements.
Start detailed checks during installation and phase them across work/payment stages so recurring defects can be corrected early. Use NESPAK records with sufficient independent evidence. Repeat visits do not count as additional sites.
Expanded checks: Expand checks for material discrepancies, safety risks, recurring defects or unreliable evidence, in consultation with the Client. Systemic defects may require checks at all affected sites. Record reasons, findings and corrective checks. Minimum coverage shall not justify unsupported payment/acceptance.
The RFP shall specify instructions, scope and payment arrangements for additional detailed inspections beyond the 20% baseline. Complete all checks by the relevant COD.
Utility-scale coverage: Cover all four utility sites, including all delivered materials, installed systems and civil works. Apply approved inspection and test plans and expand testing where defects warrant it. Full coverage does not require destructive testing of every item.
Reports shall separate document review, basic checks and detailed verification, listing sites, selection, expansion, limitations and actions. Detailed rooftop checks below follow the sampling/expansion method; basic checks and document review cover every site.
8.   Rooftop technical checks
Solar modules: Check make/model, ratings, serial records, certificates, warranties and origin against approvals. Cross-check installed identity and expand where differences arise. Inspect damage, discoloration and delamination; check orientation, tilt, spacing, mounting and strings. Use thermal imaging of representative strings for hot spots and faults.
Mounting structures: Check members, roof foundations, anchors/ballast, bolt torque, galvanization, corrosion protection, wind-load provisions and structural condition against approved designs.
Inverters: Check ratings, certificates, firmware, serials, warranties, installation, ventilation, settings and communications. Check commissioning records, protection, anti-islanding, fault detection and monitoring.
BESS: Check chemistry, capacity, identity, certificates and warranties; modules, racks, enclosures, BMS, power conversion and protection; state of charge, alarms, fault logs, communications, temperature control/HVAC, fire systems and emergency shutdown, as required by approved designs, contracts and mandatory safety requirements.
Electrical and monitoring systems: Check AC/DC cables, sizing, routing, supports, trays, conduits, terminations, labels, junction boxes, switchgear, protection and meters. Check earthing, bonding, earth resistance, continuity, earth pits and lightning protection. Check data collection, communications, software, alarms and logging for accurate recording and transmission.
9.   Utility-scale technical checks
Civil works: Check site grading, drainage, piles and foundations, retaining structures, control buildings, equipment pads and fencing. Verify workmanship, dimensions, structural condition and compliance with approved designs.
PV arrays and inverter stations: Check array layouts, strings, fixed-tilt or tracker structures, bolt torque, cable management and equipment labels. Carry out string inspections and thermal surveys for abnormal heating, bypass-diode faults and string imbalances. Check inverters, step-up transformers, switchgear, clearances, ventilation and protection settings, and review pre-commissioning tests.
HV and electrical works: Verify solar-package switchyards and associated HV equipment, particularly the 132 kV switchyard at the 58 MW Solar Park at Bunji (Astore). Check DC collector lines, MV/HV cables, relevant overhead lines, terminations, busbars, relays, surge arresters, earthing grids and lightning protection, including measured earth resistance.
Utility BESS: Check containerized units, modules/racks, BMS, Power Conversion Systems (PCS), plant BESS energy management, HVAC, sub-zero heating, fire protection, explosion protection and emergency shutdown as applicable to approved designs and contract requirements. Review safety certificates, warranties and cycle-life, capacity and degradation guarantees. Verify commissioning performance; long-term guarantees require document review only.
Plant controls: Check plant-level C&C/SCADA, data collection, real-time controls, alarms, communications, event records, dashboards, data accuracy and PV/BESS interfaces with the Grid Control Centre/EMS. This does not extend to excluded project-wide systems.
Drone surveys: Conduct monthly construction and comprehensive commissioning drone surveys at each utility site, subject to permissions/security restrictions. Provide mapped images, photographs and reports on progress, layouts, defects and site conditions. Propose equivalent methods for Client approval where flying is restricted.
10.   Factory tests, commissioning and performance:   Witness FAT at approved points for modules, inverters, structures and BESS; for utility sites also cover transformers, HV switchgear, containerized BESS and critical plant C&C/SCADA functions.
Review procedures and results, record deviations and verify corrective action before recommending dispatch. Review earlier FAT records where testing took place before TPV mobilization.
FAT professional time is included. EPC contractors pay travel/lodging only as expressly contracted and verified by the Client. The RFP shall identify uncovered costs and prevent double charging. No fixed FAT visit count is assumed at EOI stage.
Witness applicable Site Acceptance Tests (SAT), commissioning, grid-code and contractual COD tests. Check synchronization, low/high-voltage ride-through and active/reactive power control at the interconnection point.
Verify the ten-day continuous utility performance run where required by the EPC contract. If the contract specifies a different period or condition, apply that requirement and seek Client direction on the difference before testing. Refer tests falling after COD to Client/NESPAK.
During contractual commissioning/COD tests, verify PV capacity, energy generation, specific yield, Performance Ratio (PR), availability and reliability. Check BESS usable capacity, round-trip efficiency, response times, availability, SOC accuracy and initial State of Health against contractual acceptance criteria and available manufacturer/test records.
Check SCADA, solar EMS interfaces and remote RTUs for data accuracy, alarms, reporting, stored data and communication availability. Compare results against contracts, approved designs and specifications. Report deficiencies and corrective actions before COD recommendations.
Record test conditions, instrument calibration, results, sample selection and limitations. Distinguish visual checks from thermal imaging and electroluminescence (EL) testing. Review available factory EL records; undertake additional EL where required by contract or justified by findings and duly instructed. Do not assume EL testing of every module or claim that visual checks rule out hidden defects.
11.   Digital records and asset register: Set up the Digital Inspection Management System (DIMS) and GIS register structure with initial data within 30 days. Complete entry of available records within 60 days.
Provide inspection planning, mobile forms, geo-tagged/timestamped evidence, asset/NCR/corrective-action tracking, dashboards and reports, with Client access, secure storage and backups.
Map all rooftop/utility sites, BESS and solar infrastructure. Record site/building identity, district, GPS and contractor; PV capacity, module numbers, make/model, serials and warranties; inverter ratings/identity/warranties; BESS chemistry, capacity, identity, warranties and commissioning date; and transformer, switchgear, protection and metering details.
Record inspection, compliance, NCR and COD-readiness status. Separate rooftop document review, basic checks and detailed verification, with dates, evidence and limitations.
Maintain organized photographic, drone and thermal-image records linked to inspections. Thermal checks shall cover relevant modules, combiner boxes, connections, switchgear, transformers, terminations, distribution boards, batteries and PCS.
Update records through each site's COD and hand over complete records, usable exports, documentation and administrative access by the last solar COD. Post-COD hosting, operation, maintenance and updating are the Client's responsibility.
12.   Defects and corrective action: Maintain a register of Non-Conformance Reports (NCRs), showing the defect, site/equipment, requirement, responsible party, target date, evidence, classification, status and closure history.
Critical NCR: For immediate safety risks or conditions preventing safe/reliable operation, notify the Client, NESPAK and contractor immediately and issue a written NCR within 48 hours. Do not recommend affected commissioning, acceptance or milestone payment until satisfactory closure is independently verified.
Major NCR: For defects materially affecting design, specification, contractual compliance or performance without an immediate safety risk, issue an NCR within five working days. Close it before the relevant Verification Certificate or Commissioning Compliance Report.
Minor NCR: Track localized defects that do not materially affect safety, compliance or performance. Seek closure normally within 30 days or another period agreed with the contractor and accepted by the Client. Hand over minor items still open at COD to Client/NESPAK without extending TPV services or waiving acceptance conditions.
Observations: Record improvement opportunities and emerging risks. Formal corrective tracking is required only if the item is reclassified as an NCR.
Escalate seven or more similar Minor NCRs across sites, or recurring at the same site after reported closure, as a systemic Major NCR. Notify the Client, consider expanded checks and report open and closed NCRs monthly.
13.   Reports and deliverables:Â
Provide:
•   Inception report and verification methodology within 15 calendar days, covering staffing, risks, coverage, sampling, test methods, acceptance criteria, reporting and COD planning.
•   Procurement, design, historical payment and milestone reports within the periods stated above.
•   Monthly reports within ten days of month-end: progress, procurement/payments, risks, NCRs/actions, rooftop coverage by lot and all utility-site findings.
•   Quarterly technical audits of design compliance, quality, safety, progress and commissioning performance, with the related monthly report.
•   FAT/SAT, commissioning and performance reports within five working days of witnessing/complete evidence, before recommendations and by COD. Report urgent failures immediately.
•   Separate procurement, rooftop, utility and BESS verification records after the relevant checks and closure of Critical/Major NCRs.
•   Final site/lot findings by applicable COD and consolidated validation, COD recommendations and digital handover by the last solar COD.
Submit editable and searchable PDF reports with measurements, calculations, tests and photos. State requirements, evidence, findings, limitations and actions; include partial reporting periods in COD reports.
Submit draft final findings early enough for Client review. The Client shall review reports within 14 calendar days; the Consultant shall address comments within five working days. Plan these steps to finish by COD. No reporting period creates a post-COD extension. Record unresolved matters for Client/NESPAK follow-up.
Promptly report access/record delays, impacts and mitigation. Extensions follow the contract and do not allow unsupported certification. Client review does not remove TPV responsibility.
14.   Personnel and resources: Provide the following ten disciplines: Team Leader/Renewable Energy Expert; Solar PV Expert; BESS Expert; Senior Electrical Engineer; Senior Civil Engineer; QA/QC Expert; HSE Expert; Monitoring and Data Systems Expert; Procurement Expert; and Quantity Surveyor.
Use qualified inspectors under specialist oversight for all rooftop basic checks. Specialists/inspectors shall perform detailed/expanded rooftop checks and full utility coverage. Combine visits where practical.
Provide field presence, calibrated instruments, transport, communications, digital tools and specialist testing. Detailed qualifications and inputs shall be specified at RFP stage; EOI evidence is limited to published corporate capability requirements.
Initial deadlines run from commencement; days are calendar unless stated. Working days are the Client's Islamabad working days, excluding public holidays. Read with the detailed EOI TORs and Data Sheet.