Find candidate POIs for your land

1. What the point of interconnection is

The POI is a contractual and physical point, not a line on a map: it is where the generator's facilities end and the transmission provider's begin, and it is defined in the interconnection agreement. ERCOT and FERC-jurisdictional markets define it in similar terms, and both separate it from the point where ownership changes hands. Everything else on this page follows from where that point is placed.

• In the ERCOT Standard Generation Interconnection Agreement (SGIA), the Point of Interconnection is the negotiated location where the generator's interconnection facilities (GIF) meet the TSP's interconnection facilities (TIF).
  “"Point of Interconnection" shall mean the location(s) where the GIF connects to the TIF as negotiated and defined by the Parties”
  Oncor / Innovative Solar 341 LLC ERCOT Standard Generation Interconnection Agreement, PUCT Project No. 35077, Item 955 (Exhibit A, Art. 1, Sec. 1.13) (executed April 30, 2019; filed May 22, 2019) · 2019-04-30
• The SGIA defines the two sets of facilities that meet at the POI: GIF (generator-owned) and TIF (TSP-owned), each described in Exhibit C of the agreement.
  “"TIF" shall mean the TSP's interconnection facilities as described in Exhibit "C" to this Agreement.”
  Oncor / Innovative Solar 341 LLC ERCOT Standard Generation Interconnection Agreement, PUCT Project No. 35077, Item 955 (Exhibit A, Art. 1, Sec. 1.20; GIF at Sec. 1.8) (executed April 30, 2019; filed May 22, 2019) · 2019-04-30
• ERCOT's RRGRR025 / NPRR1005 revised the Protocol term 'Point of Interconnection' to match the SGIA's concept of the POI as the point where ownership changes, and added the separate term 'Point of Interconnection Bus (POIB)' for the substation bus downstream of that point.
  “modify the existing term POI to conform to the SGIA's conception of the POI as the point of ownership change.”
  ERCOT Board Report, RRGRR025 'Clarify Definition of Point of Interconnection (POI) and Add Definition Point of Interconnection Bus (POIB)' (related to NPRR1005), filed in PUCT Project 52307 · 2021-08-10
• Oncor's generator interconnection standard defines the POI as the physical conductor connection where ownership changes between Oncor and the generator, with the exact point fixed in the Interconnection Agreement.
  “The point where the Company's conductors are connected to the Generator's conductors and a change of ownership occurs,”
  Oncor Transmission Standard 520-108, Guideline - Facility Interconnection Requirements for Points of Interconnection at Transmission Voltages with Generators (Sec. 2.10), last revision November 21, 2023 · 2023-11-21
• Under FERC's pro forma LGIP/LGIA (post-Order 2023), the Point of Interconnection is the point where the Interconnection Facilities connect to the Transmission Provider's Transmission System; the separate 'Point of Change of Ownership' is where the customer's interconnection facilities connect to the Transmission Provider's interconnection facilities.
  “Point of Interconnection shall mean the point, as set forth in Appendix A to the Standard Large Generator Interconnection Agreement, where the Interconnection Facilities connect to the Transmission Provider's Transmission System.”
  FERC pro forma Standard Large Generator Interconnection Procedures (LGIP), Appendix B to pro forma OATT, updated August 20, 2024 (Section 1, Definitions) · 2024-08-20
• FERC's pro forma definition of 'Point of Change of Ownership' is distinct from the POI: it marks where customer-owned interconnection facilities hand off to Transmission Provider-owned interconnection facilities.
  “where Interconnection Customer's Interconnection Facilities connect to Transmission Provider's Interconnection Facilities.”
  FERC pro forma Standard Large Generator Interconnection Procedures (LGIP), Appendix B to pro forma OATT, updated August 20, 2024 (Section 1, 'Point of Change of Ownership') · 2024-08-20

2. Public data for finding candidate lines and substations

Before anything is filed, the candidates come from public map and tabular data. Each source below does one job and has limits the entries state: the federal transmission layer shows lines, not room to connect; the EIA forms show existing and planned plants; ERCOT's monthly status report shows every request already in the queue with its POI; parcel data shows who holds the substation site. The planning models that would answer the capacity question directly are not public.

• ERCOT publishes a monthly, public Generator Interconnection Status (GIS) Report (data product PG7-200-ER) covering planned generation resources in the interconnection process.
  “View the latest public interconnection information on planned generation resources in the ERCOT Region.”
  ERCOT Resource Adequacy page (GIS Report, data product PG7-200-ER) · 2026-10-18
• Since March 2026 ERCOT's monthly GIS file series also includes TSP-reported interconnection costs for transmission-connected generators that received an initial energization date in the prior month (data product pg7-201-er).
  “Interconnection Cost Reporting for Transmission-Connected Generators in the ERCOT region.”
  ERCOT Resource Adequacy page (GIS Report for Transmission Interconnection Costs, pg7-201-er) · 2026-10-18
• The monthly GIS report includes the financial security amount, added by PGRR088 ('Include Financial Security Amount in the Monthly Generator Interconnection Status Report').
  “Include Financial Security Amount in the Monthly Generator Interconnection Status Report”
  ERCOT approved PGRR list, PGRR088 (title) · 2020-09-28
• ERCOT's SSWG steady-state base cases (the planning models used for interconnection screening) are available to registered Market Participants, not to the general public.
  “The base cases created by the Steady-State Working Group (SSWG) and System Protection Working Group (SPWG) are available for use by Market Participants.”
  ERCOT Planning Guide (complete PDF, August 1, 2026), Section 4.1(7) · 2026-08-01
• The HIFLD transmission lines layer (Oak Ridge National Laboratory for the HIFLD Subcommittee) covers lines from 69 kV to 765 kV; where no authoritative source existed, geometry was digitized from imagery, and no topology tests were run.
  “Lines are operated at relatively high voltages varying from 69 kV up to 765 kV”
  HIFLD 'Transmission_Lines' ISO-19139 metadata (originator Oak Ridge National Laboratory; publication 2024-09-30) · 2024-09-30
• Form EIA-860 collects generator-level data for existing and planned generators at plants of 1 MW or more; it is annual (final 2025 data released September 10, 2026) and its data files include Utility, Plant and Generator files, among others.
  “collects generator-level specific information about existing and planned generators”
  U.S. EIA, Form EIA-860 Annual Electric Generator Report · 2026-09-10
• EIA-860M (Preliminary Monthly Electric Generator Inventory) tracks existing and proposed units monthly, but its capacities are preliminary estimates, not commitments.
  “reported capacities are EIA's preliminary estimates of capacity for that month.”
  U.S. EIA, Preliminary Monthly Electric Generator Inventory (EIA-860M) · 2026-09-24
• The PUCT's published CCN GIS downloads cover only retail water and sewer service areas; electric transmission-line CCN routes are not offered as a statewide GIS layer on that page.
  “PUCT's official digital mapping data includes certificated service areas for retail water and sewer utilities.”
  PUCT, CCN Mapping Information · 2026-10-18
• Texas statewide parcel data (TxGIO StratMap Land Parcels) is compiled from county appraisal districts, refreshed roughly annually, and is explicitly not survey grade.
  “They are not survey grade and should not be used for legal purposes.”
  Texas Geographic Information Office (TxGIO), StratMap Land Parcels · 2026-10-18
• USGS 3DEP 1/3 arc-second DEMs (about 10 m resolution) provide seamless terrain elevation for the conterminous U.S., useful for gen-tie routing and site grading screens.
  “1/3 arc-second (approximately 10 m) resolution”
  USGS National Map 3DEP, 1/3rd arc-second Digital Elevation Models (DEMs) collection (data.gov record) · 2025-02-14

3. Voltage class and the interconnection design

ERCOT's transmission system starts at the voltage its planning criteria set, and the utilities build interconnections at three nominal classes. No ERCOT or utility document states a rule of thumb for how many megawatts each class can take; the capacity is fixed in the agreement after study. What the utility standards do say is how the connection is built: a radial dead-end at a utility-owned structure in one territory, a loop-in to a new ring-bus substation in a real agreement in another, and breakers rated for the fault current at the point.

• ERCOT's planning criteria treat 60 kV and above as the transmission system; this is the voltage floor for Planning Guide reliability criteria and RPG project review.
  “The ERCOT System consists of those generation and Transmission Facilities (60 kV and higher voltages)”
  ERCOT Planning Guide (complete PDF, August 1, 2026), Section 4.1(2) · 2026-08-01
• Oncor's transmission voltages are 69 kV, 138 kV and 345 kV; the MW capacity of an interconnection is specified in the Interconnection Agreement.
  “Company's transmission voltages are 69 kV, 138 kV, and 345 kV.”
  Oncor Transmission Standard 520-108, Guideline - Facility Interconnection Requirements for Points of Interconnection at Transmission Voltages with Generators (Sec. 3.4.1; MW at Sec. 3.4.2) · 2023-11-21
• Oncor states the MW capacity of a generator interconnection is fixed in the Interconnection Agreement rather than by voltage class.
  “The MW capacity will be specified in the Interconnection Agreement.”
  Oncor Transmission Standard 520-108, Guideline - Facility Interconnection Requirements for Points of Interconnection at Transmission Voltages with Generators (Sec. 3.4.2) · 2023-11-21
• LCRA TSC lists the same three nominal transmission voltages used across ERCOT.
  “Transmission Service Voltages (nominal): 69-kV, 138-kV, or 345-kV.”
  LCRA Transmission Services Corporation Facility Interconnection Requirements (Sec. 3.1), January 2026 · 2026-01-01
• LCRA TSC's generator interconnection design puts the generator on a radial circuit dead-ended at an LCRA-owned POI structure, with LCRA breakers on every element connected to the POIB; LCRA's ultimate station plans may be ring bus, breaker-and-a-half or double-bus double-breaker.
  “may include a ring bus, breaker-and-a-half, or double bus double breaker configurations.”
  LCRA Transmission Services Corporation Facility Interconnection Requirements (Sec. 3.3; radial circuit at Sec. 4.8) · 2026-01-01
• Oncor requires generator transmission-voltage breakers to be rated to interrupt available fault current.
  “The breaker duty of Generator's transmission voltage breakers shall be capable of interrupting available faults”
  Oncor Transmission Standard 520-108, Guideline - Facility Interconnection Requirements for Points of Interconnection at Transmission Voltages with Generators (Sec. 3.5.1) · 2023-11-21
• A real ERCOT example of a 345 kV POI built as a loop-in rather than a tap: Oncor looped the Bell County East-TNP One 345 kV line into a new three-breaker ring-bus switching station (Gristmill Switch) to serve a solar+BESS project.
  “from a 345 kV three breaker, ring bus arrangement, and shall include the following facilities.”
  Oncor / Yaupon Solar LLC ERCOT Standard Generation Interconnection Agreement (24INR0042, 24INR0169), PUCT Project No. 35077, Item 1683 (Exhibit C, Item 8) (executed September 28, 2023; filed October 13, 2023) · 2023-09-28
• NERC FAC-001-3 obliges every Transmission Owner to document its facility interconnection requirements, update them as needed, and make them available upon request, which is why TSP interconnection standards exist.
  “Each Transmission Owner shall document Facility interconnection requirements, update them as needed,”
  NERC Reliability Standard FAC-001-3, Facility Interconnection Requirements (Requirement R1) · 2019-10-01

4. Getting capacity information before and after filing

In ERCOT the capacity answer comes from the operator's own studies, in a fixed order, after a request is accepted; the request itself asks for the POI as a county, coordinates, a description and a voltage, with proof of site control. Utilities will not begin design on their side until the agreement is signed, so early conversations with the utility are informational. FERC-jurisdictional markets took a different path after Order 2023: public heat maps and screening tools that show headroom before a cluster window opens, with the caveats each tool states.

• ERCOT's generator interconnection study procedure for large generators is organized as: Security Screening Study (5.3.1), Full Interconnection Study (5.3.2) with proof of site control, scoping, steady-state, short-circuit, stability and facility study elements, then an FIS report, plus ERCOT Economic, Reactive and Quarterly Stability assessments.
  “5.3 INTERCONNECTION STUDY PROCEDURES FOR LARGE GENERATORS / 5.3.1 Security Screening Study / 5.3.2 Full Interconnection Study / 5.3.2.1 Proof of Site Control”
  ERCOT Planning Guide (complete PDF, August 1, 2026), Section 5 table of contents · 2026-08-01
• An Interconnecting Entity starts the process by submitting a Generation Interconnection or Modification request (INR) through ERCOT's online RIOO-IS application.
  “After you electronically submit your INR with your fee payment, ERCOT has 10 days to review it for technical accuracy.”
  ERCOT, 'Creating an INR for a Generation Resource Over 10MW' (RIOO-IS user guide), Version 12.31.21, p. 1 · 2021-12-31
• The INR form asks for the POI as county, decimal latitude/longitude, a location description and the primary kV at the point of interconnection.
  “Type in the primary kilovolt level at the point of interconnection.”
  ERCOT, 'Creating an INR for a Generation Resource Over 10MW' (RIOO-IS user guide), p. 11 · 2021-12-31
• Proof of site control is uploaded with the INR, and the Screening Study starts only after ERCOT accepts the INR as materially complete; the Screening Study fee is non-refundable.
  “ERCOT sends you an email notifying you that the INR is accepted and starts your Screening Study.”
  ERCOT, 'Creating an INR for a Generation Resource Over 10MW' (RIOO-IS user guide), p. 21 (fee non-refundable at p. 17) · 2021-12-31
• ERCOT describes its interconnection process as 18 to 30 months for large generation (>=10 MW), organized in stages beginning with the GINR request, Screening Study, FIS/SSR, Reactive Study and QSA.
  “ERCOT process is 18 to 30 months for Large Generation (>=10 MW)”
  ERCOT, 'ERCOT Interconnection Process' (J. Fernandes, Manager Resource Integration), Generation Entity Winter Weather Preparedness Workshop, slide 2 (stages at slide 9) · 2024-10-28
• ERCOT's Resource Integration department is the contact for interconnection questions; fees are set in the ERCOT Fee Schedule within the Protocols.
  “ResourceIntegrationDepartment@ercot.com”
  ERCOT Resource Integration page · 2026-10-18
• Oncor requires an Interconnection Agreement to establish an interconnection and has no obligation to begin design, procurement of materials or construction of its facilities until the Interconnection Agreement is entered, so pre-agreement engagement with the TSP does not commit the TSP to build.
  “In order to establish an interconnection with Company, Generator is required to enter an”
  Oncor Transmission Standard 520-108, Guideline - Facility Interconnection Requirements for Points of Interconnection at Transmission Voltages with Generators (Sec. 3.18) · 2023-11-21
• FERC Order No. 2023 (July 28, 2023) requires FERC-jurisdictional transmission providers to maintain a public heatmap-style view of available transmission capacity and moves them to first-ready, first-served cluster studies.
  “the final rule requires transmission providers to maintain a publicly available visual representation”
  FERC, Explainer on the Interconnection Final Rule (Order No. 2023) · 2023-07-28
• Under the FERC pro forma LGIP, interconnection requests are accepted during a 45-calendar-day Cluster Request Window; the application fee is $5,000 plus a tiered study deposit ($35,000 + $1,000/MW below 80 MW; $150,000 for 80-<200 MW; $250,000 at 200 MW+).
  “Transmission Provider shall accept Interconnection Requests during a forty-five (45) Calendar Day period.”
  FERC pro forma Standard Large Generator Interconnection Procedures (LGIP), Appendix B to pro forma OATT, updated August 20, 2024 (Sec. 3.4.1; deposits at Sec. 3.1.1.1) · 2024-08-20
• Order 2023 requires 90% site control at submission and 100% by the facilities study agreement, plus commercial readiness deposits at each study stage.
  “must provide evidence of 90% site control at the time of submission”
  FERC, Explainer on the Interconnection Final Rule (Order No. 2023) · 2023-07-28
• MISO already operated a heat map (the 'POI Tool') when Order 2023 took effect and considered itself already compliant on that point; it also sought to maintain its three-phase Definitive Planning Phase cycle and 100% site-control requirement.
  “MISO already utilizes a heat map*”
  MISO, FERC Order No. 2023: Workshop (slide 8; site control slide 25) · 2024-02-21
• PJM's Queue Scope tool lets a developer screen a candidate POI and MW injection for thermal headroom before entering the PJM process, but it is linear, summer-peak, thermal-only and not a substitute for PJM studies.
  “is not intended to be a substitute for actual interconnection studies conducted by PJM.”
  PJM, Queue Scope User Guide, Revision 3 (August 2024) · 2024-08-12
• SPP's Hosting Capacity Tool (interactive map) shows percent loading on monitored facilities from the most recent posted DISIS models, decrements for all generation at the same POI, cannot show transmission lines because of CEII restrictions, and must be updated within 30 days after each cluster study and restudy per FERC.
  “The tool decrements for all generation at the same POI.”
  SPP, Hosting Capacity Tool (HCT) User Interface Guide and FAQs, revised 7/16/2026 · 2026-07-16
• CAISO's public Points of Interconnection heatmap shows available capacity by POI from a transfer-limit (P1 contingency) assessment, is informational only, and is refreshed about three times a year after cluster studies.
  “available capacities displayed in the POI Heatmap are for information only.”
  CAISO, Public Points of Interconnection Heatmap FAQs · undated; accessed 2026-10-18

5. Reading the queue around a candidate POI

A request joins whatever is already studied at that point. ERCOT treats interconnection-driven transmission work differently from other grid projects, two projects can share one POI under a contractual cap, and screening constraints can rule a point out before capacity is even the question. The county pages on this site list every ERCOT request by POI and stage, which is where this reading starts.

• ERCOT treats generation-interconnection-driven transmission projects differently from other grid projects: they are exempt from formal Regional Planning Group review, so the GIS report and FIS, not the RPG process, are where POI-level upgrade information appears.
  “projects that are directly associated with the interconnection of new Generation Resources and Energy Storage Resources (ESRs),”
  ERCOT Planning Guide (complete PDF, August 1, 2026), Section 3.1.1.3(1) · 2026-08-01
• Two projects can share one POI with a contractual cap on combined output: in the Yaupon SGIA, solar (24INR0042) and BESS (24INR0169) share a single 345 kV POI limited to 200.8 MW.
  “The combined Solar and BESS output will not exceed 200.8 MW measured at the Point of Interconnection.”
  Oncor / Yaupon Solar LLC ERCOT Standard Generation Interconnection Agreement (24INR0042, 24INR0169), PUCT Project No. 35077, Item 1683 (Exhibit C) (executed September 28, 2023; filed October 13, 2023) · 2023-09-28
• The FERC pro forma LGIP requires cluster request lists to be anonymized, so FERC-market queue postings identify the substation/line and MW but not the developer.
  “must ensure that project information is anonymized and does not reveal the identity.”
  FERC pro forma Standard Large Generator Interconnection Procedures (LGIP), Appendix B to pro forma OATT, updated August 20, 2024 (Sec. 3.4.5) · 2024-08-20

6. The gen-tie, ownership on each side, and whether a certificate is needed

The agreement decides who builds and owns what on each side of the POI and who provides right-of-way. In Texas, whether a generator's own line needs a certificate of convenience and necessity comes from reading several provisions together rather than one sentence; the entries below give each provision so the combination can be checked.

• Under the ERCOT SGIA the generator builds, owns and pays for the Plant and GIF; the TSP builds, owns and pays for the TIF, subject to any contribution in aid of construction listed in Exhibit C.
  “The Generator will acquire, construct, operate, test, maintain and own the Plant and the GIF at its sole expense.”
  Oncor / Innovative Solar 341 LLC ERCOT Standard Generation Interconnection Agreement, PUCT Project No. 35077, Item 955 (Sec. 8.1; TSP at Sec. 8.2) (executed April 30, 2019; filed May 22, 2019) · 2019-04-30
• The TSP side of the POI is designed, procured and constructed by the TSP.
  “The TSP shall design, procure, and construct the TIF, using Reasonable Efforts”
  Oncor / Innovative Solar 341 LLC ERCOT Standard Generation Interconnection Agreement, PUCT Project No. 35077, Item 955 (Sec. 4.1.A; ownership at Sec. 8.2) (executed April 30, 2019; filed May 22, 2019) · 2019-04-30
• The SGIA can require the generator to procure right-of-way for new TSP line work and to grant the TSP easements at no cost.
  “The Right of Way in which the new line is to reside will need to be procured by the Generator.”
  Oncor / Innovative Solar 341 LLC ERCOT Standard Generation Interconnection Agreement, PUCT Project No. 35077, Item 955 (Exhibit C, Item 8; easement grant at Exhibit C Sec. 12(c)) (executed April 30, 2019; filed May 22, 2019) · 2019-04-30
• The PUCT adopted an updated ERCOT Standard Generation Interconnection Agreement in Project No. 58211 on November 6, 2025; it took effect January 1, 2026, all new SGIAs executed on or after that date must use it, and amendments to earlier SGIAs use the old form.
  “All new SGIAs executed on or after January 1, 2026 must use the updated SGIA.”
  ERCOT Market Notice M-A120125-02, Updated Standard Generation Interconnection Agreement (SGIA) and Amendments · 2026-01-14
• The interconnection allowance (how much of the TSP's interconnection cost is absorbed rather than charged to the generator) is governed by PUCT rule 16 TAC 25.195, which the SGIA notice points to.
  “Refer to 16 Texas Administrative Code Section 25.195 for requirements related to the interconnection allowance.”
  ERCOT Market Notice M-A120125-02 · 2026-01-14
• A Texas power generation company may own an 'essential interconnecting facility' (its gen-tie) without becoming an electric utility; PGCs are excluded from the PURA definition of electric utility.
  “does not own a transmission or distribution facility in this state other than an essential interconnecting facility, a facility not dedicated to public use”
  Texas Utilities Code (PURA) Sec. 31.002(10)(B) 'Power generation company'; exclusion at Sec. 31.002(6)(C) · 2023-09-01
• PURA's CCN requirement in Sec. 37.051(a) applies to an electric utility providing service to the public under a franchise or permit; the (c-1) certificate requirement applies to a facility interconnected to the ERCOT grid that enables additional power to be imported into or exported out of ERCOT, which an ordinary intra-ERCOT gen-tie does not do.
  “a person, including an electric utility or municipally owned utility, may not interconnect a facility”
  Texas Utilities Code Chapter 37, Sec. 37.051(c-1) (with (a)) · 2019-05-16
• A TSP's short line extension to a generation substation (up to two miles) is a 'routine activity' not requiring a CCN under PUCT rule 25.101, provided ROW is acquired and affected landowners consent in writing; a new switching station or substation also needs no CCN.
  “(II) two miles if the line connects to a generation substation or metering point; and”
  16 Tex. Admin. Code Sec. 25.101(c)(5)(A) (substation at (c)(2)) · 2022-12-20

7. ERCOT-specific rules that touch the POI

Three sets of rules change how a POI is used after it is chosen: the commissioning time limit that runs from synchronization approval, the large-load law and its study process for data centers that want to sit at a generator's point, and the notice required before a co-location arrangement. Batteries follow the same section as generators.

• PGRR103 (effective 11/01/2023) requires an Interconnecting Entity to complete all conditions for commercial operation of a Generation Resource or ESR within 180 days of ERCOT's approval for Initial Synchronization.
  “within 180 days of receiving approval for Initial Synchronization from ERCOT.”
  ERCOT Market Rules issue page: PGRR103, Establish Time Limit for Generator Commissioning Following Approval to Synchronize · 2023-11-01
• PGRR103 applies the same commissioning time limit to Energy Storage Resources as to Generation Resources, confirming batteries follow the same Section 5 interconnection path.
  “to complete all conditions for commercial operation of a Generation Resource or Energy Storage Resource (ESR)”
  ERCOT Market Rules issue page: PGRR103 (Description) · 2023-11-01
• Texas SB 6 (89th Legislature, 2025) directs the PUCT to set large-load interconnection standards with a 75 MW demand threshold and a flat study fee of at least $100,000 for initial transmission screening.
  “set a flat study fee of at least $100,000 to be paid”
  Texas Legislature, Bill Analysis for enrolled S.B. 6 (89R) (PURA Sec. 37.0561), Senate Research Center analysis dated August 5, 2025 (bill signed and effective June 20, 2025) · 2025-08-05
• SB 6 requires large-load customers to disclose whether they are pursuing substantially similar interconnection requests elsewhere in Texas, and to demonstrate site control.
  “whether the customer is pursuing a substantially similar request for electric service in this state.”
  Texas Legislature, Bill Analysis for enrolled S.B. 6 (89R) (PURA Sec. 37.0561), Senate Research Center analysis dated August 5, 2025 (bill signed and effective June 20, 2025) · 2025-08-05
• SB 6 adds PURA 39.169: a power generation company, municipally owned utility or electric cooperative must notify ERCOT before implementing a net-metering (co-location) arrangement between a registered operating facility and a new large load; ERCOT studies the system impacts and the PUCT may approve, deny or impose reasonable conditions on it.
  “the system impacts of a proposed net metering arrangement and removal of generation.”
  Texas Legislature, Bill Analysis for enrolled S.B. 6 (89R) (PURA Sec. 39.169), Senate Research Center analysis dated August 5, 2025 (bill signed and effective June 20, 2025) · 2025-08-05

8. The checklist, step by step

The order a developer follows, each step pointing at the sourced entries above. The entries in this section are the few steps that carry a sourced statement of their own; the rest of the procedure is in the numbered list that follows them.

• Checklist step: confirm the candidate line is transmission (60 kV+) under ERCOT criteria and identify its nominal class (69/138/345 kV) from the TSP's standard.
  “The ERCOT System consists of those generation and Transmission Facilities (60 kV and higher voltages)”
  ERCOT Planning Guide (complete PDF, August 1, 2026), Section 4.1(2); Oncor 520-108 Sec. 3.4.1 · 2026-08-01
• Checklist step: plan the gen-tie as generator-owned GIF up to the POI and expect the TSP to own the TIF, with ROW for any TSP line work potentially procured by the generator.
  “The TSP will acquire, own, operate, test, and maintain the TIF at its sole expense”
  Oncor / Innovative Solar 341 LLC ERCOT Standard Generation Interconnection Agreement, PUCT Project No. 35077, Item 955 (Sec. 8.2) (executed April 30, 2019; filed May 22, 2019) · 2019-04-30
• Checklist step: once synchronized, the project must reach commercial operation within 180 days (PGRR103), so POI construction scope must be closed out before Initial Synchronization.
  “within 180 days of receiving approval for Initial Synchronization from ERCOT.”
  ERCOT Market Rules issue page: PGRR103 · 2023-11-01

1. Fix the site, then look outward. With the parcel outline known, run the land report for the point and open the map with the transmission layer on. Note every mapped line within a few miles and its listed voltage, remembering the layer's vintage (section 2).
2. Sort the candidates by voltage class. Keep the lines at or above the transmission floor and name each one's nominal class from the utility's own standard, not from the federal map alone (section 3).
3. Find the substations and who owns them. Use the existing-plant and planned-plant data for interconnections already built nearby, and the parcel layer for the substation site owner, which tells you which utility to call (section 2).
4. Read the queue at each candidate. Open the county page and list every request on the same POI with its stage and size; a crowded point is studied as a group and the agreement at a shared point can cap combined output (section 5).
5. Screen out the constraints that are not about capacity. Screening-stage constraints can remove a point before capacity is studied (the Security Screening Study entry in section 4); the large-load rules matter if a data center is part of the plan (section 7).
6. Talk to the utility, knowing what it can and cannot say. The utility's standard describes how it will build the connection; it will not design until the agreement is signed, and the planning cases it works from are not public (section 4).
7. Price the gen-tie and the right-of-way. Decide the route from the plant to each candidate POI, who owns each side, and what easements the agreement will ask you to provide; check the certificate question for your own line against the provisions listed (section 6).
8. File with the POI stated the way the form asks, with site control in hand, and let the operator's studies settle the capacity and the cost; keep the schedule in view, including the time limit that runs after synchronization (section 4, section 7).
9. In a FERC-jurisdictional market, do steps 1–7 against that operator's heat map or screening tool before the cluster window, and meet the site-control and deposit rules the window requires (section 4).