Texas Railroad Commission Form H-1A, Injection Well Data, is the technical attachment to Form H-1 that every operator must file when they apply for a new fluid injection or disposal well permit or amend an existing one with the Railroad Commission of Texas (RRC) Oil and Gas Division. The form carries a revision date of 05/2004, so check the bottom of your copy to confirm you are using the current version before you write anything on it.
You cannot get an injection or disposal permit in Texas without it, and the well construction data you enter here is exactly what the Commission’s geologists use to decide whether your well will protect fresh water and keep injected fluids where they belong. The RRC has authorized more than 55,000 active injection and disposal wells across the state, and a single wrong depth, mismatched lease ID, or missing casing detail can bounce your application back to your desk and cost you weeks of permit-review time. This guide walks you through every box on Form H-1A so you file it right the first time.
Here is what you will learn:
- 📋 What Form H-1A is, who must file it, and how it attaches to Form H-1
- 🗂️ Every document and data point you need to gather before you start
- ✍️ A line-by-line walkthrough of all 30 numbered items, with sample entries
- 👷 Three full filled-out examples for the most common real-world filings
- ⚠️ The field-level mistakes that get applications rejected and how to dodge them
What the Form Is and Who Must File It
Form H-1A is the Injection Well Data sheet that the RRC Oil and Gas Division uses to capture the construction and operating details of each well you want to inject into. It never travels alone. You attach it to Form H-1, which is the parent application for a fluid injection or disposal permit, and the two documents move through the permit-review process as one package, as spelled out in the Form H-1 instructions.
Any operator who wants to inject fluid into a reservoir productive of oil or gas must file under Statewide Rule 46, found at 16 Texas Administrative Code §3.46. Operators who want to dispose of oil and gas waste by injection into a non-productive zone file under Statewide Rule 9 at 16 TAC §3.9. In plain English, if you plan to push saltwater, produced water, or other oilfield fluid down a well, you almost certainly need Form H-1A.
The form is built for two wells per page. The Commission designed the H-1A with two identical halves, so you can list up to two wells from the same lease on one sheet. If you have more than two wells, or wells on different leases, you must use additional H-1A forms, and you must use a separate H-1A for each lease.
A quick word on what happens if you skip it. The Commission will not process a Form H-1 that arrives without a completed H-1A for each well in the project. Picture Westline Operating, LLC mailing in an H-1 for a new saltwater disposal well but forgetting the H-1A. The Austin office returns the package, the 15-day administrative clock never starts, and the well sits idle while produced water trucks pile up costs. Filing the H-1A correctly is the difference between a permit and a paperweight.
Before You Start: Documents and Information You Need
Gather everything below before you open the form. Filling out Form H-1A from memory is how depths get transposed and lease numbers get fat-fingered, and the Commission cross-checks every entry against its own records.
- Your P-5 Organization Report number. You must already hold an active P-5 to file. Without a current P-5, the Commission rejects the application outright because an unregistered operator has no standing to hold a permit.
- Current field name and field number from Commission records. The RRC matches these to its master field list, and a guessed number routes your file to the wrong reviewer.
- Current lease name and lease/gas ID number. These tie the well to a known lease; a mismatch stalls the file while staff hunt for the right lease.
- API number for each existing well. This 14-digit identifier locates the exact wellbore in the GIS system, and an error points reviewers at someone else’s well.
- The well’s total depth and date drilled. These frame the wellbore so geologists can judge confinement, and missing them triggers a deficiency letter.
- A Form GW-2 (groundwater protection letter). This surface casing determination gives you the Base of Usable Quality Water depth you enter in Item 13; without it that box is just a guess.
- Complete casing and cement records. You report surface, intermediate, long string, and liner detail in Items 16 through 19, and gaps here read as a confinement risk.
- Tubing, packer, and injection interval data. Items 20 through 23 describe how fluid stays inside the wellbore, and the Commission cannot approve a well it cannot picture downhole.
If any single item above is missing, the smart move is to wait. A held application keeps your place in line poorly, and a clean one filed a week later often clears faster than a sloppy one filed today.
Where to Get the Form and How to Access It
You download Form H-1A directly from the Railroad Commission. The official fillable PDF lives on the RRC site as the Form H-1A Injection Well Data document, and the matching Form H-1A instructions sit right beside it. Both carry the 05/2004 revision date in the corner, which is how you confirm you have the current sheet.
You can also reach the form from the Commission’s main Oil and Gas Forms library, where H-1A is grouped with its companion injection and disposal forms. The RRC builds these PDFs in Adobe Acrobat, so open the file in a real PDF reader rather than a browser preview to make sure every field saves.
A common misconception is that you file H-1A on its own through an online portal. You do not. While the RRC Online System handles many oil and gas filings, the H-1/H-1A injection and disposal permit package is a paper application mailed to the Environmental Services section in Austin with a copy to the District Office, per the Form H-1 instructions. Print the form, fill it out, and keep a clean digital copy for your records before you mail anything.
Step-by-Step: How to Fill Out Form H-1A Line by Line
Work through the items in printed order. Items 1 through 7 cover operator and lease identity at the top of the sheet; Items 8 through 30 repeat in two identical blocks, one per well. Type your entries when you can, use ALL CAPS for names, and never leave a required box blank.
Item 1: Operator Name (as shown on P-5)
This box asks for the legal name of the company or person who will operate the well. Enter the operator name exactly as it appears on your current P-5 Organization Report, in all capital letters, with no abbreviations the P-5 does not use. For example, Permian Basin Disposal Co. writes PERMIAN BASIN DISPOSAL CO if that is the P-5 spelling. If your company recently changed its name, use the name on the most recently approved P-5, not the new one you have not filed yet. The most common mistake is entering a “doing business as” name or a parent company name that does not match the P-5, which forces staff to reconcile identities and delays the permit. Many filers believe a close match is good enough, but the Commission treats the operator name as a key that must match its records character for character.
Item 2: Operator P-5 Number
This field asks for the six-digit operator number the Commission assigned when you registered your organization. Enter the number with no spaces or dashes, such as 123456. This number, not the name, is the true link to your standing, so double-check it against your P-5 approval letter. If you operate under more than one P-5 number, use the one tied to the leases in this application. The frequent error is pulling the number from an expired P-5 or a sister company, which makes the file appear to come from an operator with no authority. Some filers think the P-5 number and the lease ID are interchangeable; they are not, and swapping them sends the application into a dead end.
Items 3 and 4: Field Name and Field Number
These two boxes ask which oil or gas field the well sits in. Enter the current field name in Item 3 and the matching field number in Item 4, using the exact designation in Commission records, as the H-1A instructions direct. For example, SPRABERRY (TREND AREA) with its assigned field number. Pull these from the Commission’s field records or your prior production filings, not from local nicknames. If the well is in a wildcat or undesignated area, use the field designation the Commission currently shows for that location. The common mistake is entering an outdated field name after a field has been redesignated, which routes the file to the wrong technical reviewer. People often assume the field name is descriptive; in fact it is a controlled term that must match the Commission’s master list.
Items 5 and 6: Current Lease Name and Lease/Gas ID Number
These fields ask for the lease the well belongs to. Enter the current lease name in Item 5 and the lease or gas ID number in Item 6 as they appear in Commission records, and remember you must use a separate H-1A for each lease. For instance, SMITH “A” lease with its five- or six-digit lease ID. Take the lease ID from your most recent production or organization records so it matches exactly. If the lease was recently transferred to you, confirm the Commission shows you as operator before relying on the ID. The classic error is listing wells from two different leases on one H-1A, which violates the instructions and forces a refiling. A widespread misconception is that the lease name alone is enough; the numeric ID is what the database actually keys on.
Item 7: Distance and Direction From Nearest Town
This line asks how far the lease is from the center of the nearest town and in which direction. Fill the three blanks so the sentence reads, for example, 3 miles in a NORTHWEST direction from MIDLAND (center of nearest town). Measure from the lease to the town center, round to a sensible distance, and use a compass direction. Make sure this matches the distance and direction you publish in your newspaper notice, because the two must agree. If the lease straddles a town line, pick the nearest incorporated town and stay consistent across the whole application. The frequent mistake is letting the H-1A distance differ from the published notice, which the Commission flags as a notice defect. Many filers think this line is informal; reviewers actually use it to confirm your public notice described the right well.
Item 8: Well Number
This box asks for the well’s identifying number on the lease. Enter the current well number for an existing well, or the proposed well number for a well you have not drilled yet, exactly as the H-1A instructions describe. For example, WD-1 for a disposal well or 4 for a numbered lease well. Keep the format consistent with how the well is or will be carried on the lease. For a brand-new disposal well, choose a number that does not duplicate an existing well on the lease. The common error is reusing a number already assigned to a producing well, which creates a wellbore identity clash. Some filers believe the well number is arbitrary; the Commission ties it to the API number and the permit, so it must be deliberate and unique.
Item 9: API Number
This field asks for the unique American Petroleum Institute number that identifies the wellbore. Enter the full API number for any existing well; for an undrilled well, you may leave it blank until the well is assigned a number. A Texas API number looks like 42-329-12345. Copy it from the well’s completion record or the RRC GIS viewer rather than typing from memory. If the well has not been drilled, note that the API will follow once the drilling permit is issued. The most damaging mistake is transposing digits, which points the entire review at a different well and corrupts the area-of-review analysis. Filers sometimes assume the API and the UIC number are the same; they are distinct identifiers serving different tracking systems.
Item 10: UIC Number
This box asks for the Underground Injection Control number the Commission assigns to permitted injection and disposal wells. Enter the existing UIC number if the well already holds injection authority you are amending; leave it blank for a brand-new well that has none yet. The number is short and tied to the prior permit, so pull it from your existing permit letter. For a new well, the Commission issues the UIC number when it grants the permit. The common error is inventing a UIC number for a new well, which confuses staff into searching for a permit that does not exist. A frequent misconception is that every well already has a UIC number; only wells with current or prior injection authority do.
Item 11: Total Depth
This field asks how deep the wellbore goes. Enter the total depth in feet as a whole number, such as 7,250. Take the figure from the well’s completion or drilling record. For a proposed well, enter the planned total depth from your drilling program. The common mistake is entering the injection interval depth here instead of the actual bottom of the hole, which misleads the confinement review. Some filers think total depth and the injection interval are the same; total depth is the deepest point of the wellbore, while the injection interval (Item 23) is the zone you actually inject into.
Item 12: Date Drilled
This box asks when the well was drilled. Enter the date in a clear format such as 06/15/1998; for an undrilled well, write proposed or the planned spud date. Pull the date from the drilling or completion record. An older well may shape how much area-of-review data the Commission requires, so accuracy here matters. The frequent error is guessing the year on an old well, which can hide that the well predates modern construction standards. Filers often treat this as trivia; in fact the date helps reviewers judge whether the wellbore meets current confinement expectations.
Item 13: Base of Usable Quality Water (ft)
This field asks the depth, in feet, above which usable-quality groundwater must be protected. Enter the depth from your Form GW-2 groundwater protection letter, for example 1,150, and never estimate it. Obtain this number by filing Form GW-1 with the Groundwater Advisory Unit, which returns the Base of Usable Quality Water on Form GW-2. For disposal wells, the GW-2 should also state the Underground Source of Drinking Water depth, so set the request purpose to “Injection into Producing Zone (H1).” The most serious mistake is entering a depth that does not match the GW-2, because the Commission cross-checks it and a mismatch is an automatic deficiency. A common misconception is that you can fill this from a log alone; only the official GW-2 letter satisfies the requirement.
Item 14: Legal Description and Coordinates
This item asks where the well sits on the ground. In part (a), give the legal location with distance and direction from two survey lines, such as 467 ft FNL and 1,320 ft FWL, Section 12, Block 38, T-2-S, T&P RR Co. Survey. In part (b), add latitude and longitude if you know them, which is optional but helpful. Take the footages from the surveyed plat, not a rough sketch. If the well is undrilled, use the surveyed surface location from your plat. The common error is reversing the “from the north line” and “from the west line” footages, which places the well in the wrong spot during the area-of-review check. Filers sometimes skip the survey-line footages thinking coordinates are enough; the legal description is required, and coordinates only support it.
Item 15: New Injection Well or Amendment
This box asks whether you are seeking a brand-new permit or changing an existing one. Check New Injection Well for a first-time permit, or Injection Well Amendment and then the reason boxes (Pressure, Volume, Interval, Fluid Type) for a change, writing a brief note if you check Other. For example, an operator raising allowed pressure checks Amendment and Pressure. Match these boxes to what your cover letter and newspaper notice describe. If you are changing more than one thing, check every reason that applies. The frequent mistake is filing as “new” for a well that already has authority, which can duplicate permits and confuse the record. People often think any change is minor; the Commission treats each amendment reason as a separate review item, so under-checking the boxes can leave part of your request unapproved.
Items 16 through 19: Casing (Surface, Intermediate, Long String, Liner)
These four rows ask for the well’s casing program, with columns for casing size, setting depth, hole size, casing weight, cement class, number of sacks, top of cement, and how the top was determined. Fill each row that applies; for Item 19 Liner, if the liner does not reach the surface, enter both the top and bottom depth as the “Setting Depth,” exactly as the instructions require. For example, surface casing might read 8-5/8 in, set at 1,300 ft, 12-1/4 in hole, 24 lb, Class C, 350 sacks, top at surface, circulated. Pull every figure from the cementing and completion records. The most common mistake is leaving cement-top or sack counts blank, which reads to a geologist as a gap in zonal isolation and draws a deficiency. Many filers assume only the long string matters; the Commission reviews surface and intermediate cement just as hard because that is what protects fresh water.
Items 20, 21, and 22: Tubing Size, Tubing Depth, and Packer Depth
These boxes ask about the injection tubing and packer that keep fluid off the casing. Enter the tubing size in Item 20, the tubing depth in Item 21, and the injection tubing packer depth in Item 22, in feet, such as 2-7/8 in, 7,000 ft, and 6,950 ft. Take these from your completion or planned recompletion design. Rule 46 and Rule 9 generally expect a packer set near the injection interval, so place it accordingly. The frequent error is showing a packer set far above the injection zone without an approved exception, which violates construction rules and triggers a rejection or a $375 exception request. Some filers think they can inject down casing without tubing and packer by default; that arrangement requires a specific written exception.
Item 23: Injection Interval
This field asks the exact depth range you will inject into. Enter the top and bottom of the interval in feet in the “_ to _” blanks, for example 7,050 to 7,180. Take these depths from the well log that identifies the injection zone. Make sure this interval matches the zone described in your newspaper notice and well log. The common mistake is listing an interval that disagrees with the log or the published notice, which is a notice defect and a technical-review failure at once. Filers often confuse the injection interval with total depth; the interval is the perforated or open zone receiving fluid, which is usually well above total depth.
Items 24, 25, and 26: Cement Squeeze, Multiple Completion, Downhole Water Separation
These items capture special wellbore conditions. In Item 24, list every cement squeeze with its interval, sacks, and top of cement; in Items 25 and 26, check Yes or No for multiple completion and downhole water separation, and remember the note: a “Yes” to either requires a wellbore sketch. For example, a remedial squeeze might read 5,400 to 5,460 ft, 75 sacks, top at 5,380 ft. Pull squeeze data from the remedial work record. The frequent error is checking “Yes” to Item 25 or 26 but forgetting the wellbore sketch, which leaves the reviewer unable to picture the completion and stalls the file. Many filers think squeezes are optional history; the Commission needs them to confirm old perforations or channels are sealed off.
Items 27, 28, and 29: Fluid Type and Injection Volumes
These boxes ask what you will inject and how much. In Item 27, name each fluid type (such as produced saltwater, gas, or CO2); in Item 28, give the maximum daily injection volume for each fluid in barrels per day or mcf per day; in Item 29, give the estimated average daily volume for each fluid. For example, produced saltwater, 15,000 bpd maximum, 8,000 bpd average. Base the numbers on your operating plan and expected throughput. The common mistake is requesting an unrealistically high maximum volume without engineering support, which invites added scrutiny or a hearing. Filers sometimes leave the average blank, thinking only the maximum counts; the Commission uses both to set and check your permit limits.
Item 30: Maximum Surface Injection Pressure
This field asks the highest surface pressure you want authorized. Enter the maximum surface injection pressure in psig for liquid and, if applicable, for gas, such as Liquid 1,800 psig. Calculate a defensible figure, since the Commission caps surface pressure to keep you from fracturing the confining zone, typically using a gradient guideline. Support a high request with a step-rate test if you have one. The most serious mistake is requesting pressure above the rule gradient without justification, which guarantees a deficiency or a denial. A common misconception is that more pressure is always better to request; an unsupported number slows your permit and can flag a seismicity concern.
Three Filled-Out Examples Using Real Scenarios
Below are three of the most common ways operators complete Form H-1A. Each follows one named filer through the key items.
Scenario 1: Carlos files for a new saltwater disposal well. Carlos manages compliance for a small operator and needs a new SWD well in the Permian.
| Form Section | What Carlos Enters |
|---|---|
| Item 1, Operator Name | WESTLINE OPERATING LLC |
| Item 2, P-5 Number | 214567 |
| Items 3–4, Field / Number | SPRABERRY (TREND AREA) / its assigned number |
| Items 5–6, Lease / ID | DELGADO “B” / lease ID 298104 |
| Item 8, Well Number | WDW-1 |
| Item 13, Base of Usable Water | 1,150 ft from the GW-2 |
| Item 15, New or Amendment | Checks New Injection Well |
| Item 23, Injection Interval | 6,900 to 7,050 ft |
| Items 27–29, Fluid and Volume | Produced saltwater, 20,000 bpd max, 9,000 bpd avg |
| Item 30, Max Pressure | Liquid 1,900 psig |
Scenario 2: Janet amends a waterflood injection permit. Janet raises the allowed injection pressure on an existing enhanced-recovery well under Rule 46.
| Form Section | What Janet Enters |
|---|---|
| Item 1, Operator Name | RECOVERY ENERGY INC |
| Item 2, P-5 Number | 331902 |
| Items 5–6, Lease / ID | HALL UNIT / lease ID 115320 |
| Item 8, Well Number | 17 |
| Item 9, API Number | 42-317-30456 |
| Item 10, UIC Number | Existing UIC from the prior permit |
| Item 15, New or Amendment | Checks Amendment, then Pressure |
| Item 22, Packer Depth | 6,950 ft |
| Item 23, Injection Interval | 7,050 to 7,180 ft |
| Item 30, Max Pressure | Liquid 2,100 psig (the new request) |
Scenario 3: Marcus lists two wells on one H-1A for the same lease. Marcus permits two new disposal wells on a single lease, using both well blocks on one sheet.
| Form Section | What Marcus Enters |
|---|---|
| Items 1–2, Operator / P-5 | BASIN DISPOSAL CO / 402188 |
| Items 5–6, Lease / ID | RIVERA “A” / lease ID 507631 |
| Item 8, Well No. (block 1) | SWD-1 |
| Item 8, Well No. (block 2) | SWD-2 |
| Item 11, Total Depth (both) | 7,400 ft and 7,380 ft |
| Item 15 (both blocks) | Checks New Injection Well on each |
| Items 16–19, Casing (both) | Full casing and cement detail per well |
| Item 23, Interval (both) | 7,050 to 7,200 ft and 7,040 to 7,190 ft |
| Items 27–29 (both) | Produced saltwater with each well’s volumes |
| Separate H-1A note | A third well on a different lease needs its own H-1A |
How to File the Completed Form
Form H-1A never files by itself. You attach it to Form H-1 and mail the complete package, because the Form H-1 instructions treat the H-1A as a required attachment.
- By mail (the standard channel). Mail the original Form H-1 with all attachments, including each H-1A, to the Assistant Director, Environmental Services, Railroad Commission of Texas, P.O. Box 12967, Capitol Station, Austin, Texas 78711. Include a non-refundable $200 fee payable to the Railroad Commission of Texas, plus $150 for each requested exception to Statewide Rule 46(g)(3) or (j)(5)(B). Pay by check or money order. Mail one copy of the full application to the appropriate RRC District Office at the same time. Keep your certified-mail receipt and a full copy as proof of filing.
- Exception requests. A separate written request to deviate from construction rules, such as injecting down casing without tubing and packer, carries a $375 fee and must show good cause, as the application attachments page explains.
- Online support documents. While the H-1/H-1A package is paper, you submit the well log through the RRC Online System and include the tracking number in the application.
Required companions usually include the well log, the Form GW-2 groundwater letter, the area-of-review map and wells table, the plat of leases, proof of mailed notice, and the affidavit of published notice. If you inject fresh water, add Form H-7. Processing runs administratively only if no valid protest arrives within 15 days of publication or receipt in Austin.
What Happens After You File
Once the Austin office receives a complete package, the clock starts. If no affected person protests within 15 days of publication or receipt of the application, the Commission may process and approve the permit administratively without a hearing.
If someone protests and you request a hearing, or the Commission decides a hearing serves the public interest, the application moves to a contested-case hearing before staff issue proper notice. Technical reviewers also verify that your construction details protect groundwater and confine injected fluids, so weak entries in Items 13 through 30 can draw a deficiency letter even without a protest.
When the permit issues, the Commission assigns a UIC number and sets your authorized fluids, volumes, and maximum pressure. From that point you must monitor injection pressure and volume at least monthly and report results each year on Form H-10, the Annual Disposal/Injection Well Monitoring Report. Treat the H-1A data as your operating envelope, because exceeding the permitted pressure or volume is a violation.
Mistakes to Avoid When Filling Out the Form
- Entering an operator name that does not match the P-5, which stalls the file while staff reconcile identities.
- Using an expired or wrong P-5 number, which makes the application appear to come from an operator with no authority.
- Listing wells from two different leases on one H-1A, which violates the instructions and forces a refiling.
- Transposing digits in the API number, which points the area-of-review analysis at the wrong wellbore.
- Inventing a UIC number for a brand-new well, which sends staff hunting for a permit that does not exist.
- Putting the injection interval depth in the Total Depth box, which misleads the confinement review.
- Guessing the Base of Usable Quality Water instead of using the GW-2, which is an automatic deficiency on cross-check.
- Reversing the survey-line footages in Item 14, which places the well in the wrong location on the map.
- Leaving cement tops or sack counts blank in Items 16 through 19, which reads as a zonal-isolation gap.
- Checking “Yes” on Item 25 or 26 without attaching the required wellbore sketch, which stalls the technical review.
- Requesting a maximum pressure above the rule gradient with no support, which guarantees a deficiency or denial.
- Letting the H-1A injection interval or distance disagree with the published newspaper notice, which is a notice defect.
Do’s and Don’ts
Do: – Confirm you have a current P-5 before filing, because an unregistered operator has no standing to hold a permit. – Copy field, lease, and API numbers straight from Commission records, since the RRC cross-checks every one. – Use a separate H-1A for each lease, because the instructions require it and mixing leases forces a refiling. – Pull the Base of Usable Quality Water from the GW-2, since only that letter satisfies Item 13. – Match the injection interval and distance to your newspaper notice, because inconsistencies are treated as notice defects. – Keep certified-mail receipts and a full copy, because they are your only proof of timely filing.
Don’t: – Don’t file H-1A alone, because the Commission only processes it as an attachment to Form H-1. – Don’t guess depths from memory, since one transposed figure can trigger a deficiency letter. – Don’t set the packer high above the interval without an exception, because that breaks construction rules. – Don’t request volumes or pressure you cannot support, since unsupported numbers invite hearings and delay. – Don’t forget the wellbore sketch when you answer “Yes” to Item 25 or 26, because the reviewer needs it. – Don’t assume an online portal accepts the package, since the H-1/H-1A application is filed on paper to Austin.
Pros and Cons of Filing on Your Own vs. With a Consultant
Filing on your own (pros): – You save the consultant fee, which matters for a small operator with one well. – You learn your own well’s construction in detail, which helps with later compliance. – You control the timeline directly and can fix small errors fast. – You build a relationship with District Office staff who can answer questions. – You keep sensitive operating data fully in house.
Filing with a consultant (cons of going solo, pros of help): – A consultant knows the Rule 9 and Rule 46 nuances that trip up first-time filers. – A consultant assembles the notice, plat, and area-of-review package that often causes deficiencies. – A consultant can defend the application if a protest leads to a hearing. – A consultant spots an unrealistic pressure or volume request before it draws scrutiny. – A consultant generally clears review faster, which can be worth the fee when produced water is piling up.
FAQs
Do I file Form H-1A by itself?
No. Form H-1A is an attachment to Form H-1, and the Commission only processes the two together as one injection or disposal permit application package.
Is there a separate fee for Form H-1A?
No. The H-1A carries no separate fee; the $200 non-refundable fee is paid with the parent Form H-1, plus $150 for each Rule 46 exception requested.
Can I list more than two wells on one H-1A?
No. Each Form H-1A holds up to two wells, so you must use additional H-1A forms for more wells, and a separate form for each lease.
Do I write my operator name or the lease owner’s name in Item 1?
Yes, to the operator name. Item 1 asks for the operator name exactly as shown on your P-5, not the surface owner or mineral owner.
Do I put total depth or the injection interval in Item 11?
Yes, total depth. Item 11 wants the deepest point of the wellbore, while the injection interval you actually inject into goes in Item 23.
Do I need a UIC number in Item 10 for a brand-new well?
No. A new well has no UIC number yet, so leave Item 10 blank; the Commission assigns the UIC number when it grants the permit.
Can I estimate the Base of Usable Quality Water in Item 13?
No. You must use the depth from your official Form GW-2 groundwater letter, because the Commission cross-checks Item 13 against it.
Do I check “New” or “Amendment” when raising my pressure limit?
Yes, Amendment. Check the Amendment box in Item 15 and the Pressure reason box, since the well already holds injection authority you are changing.
Is the API number the same as the UIC number?
No. They are distinct identifiers; the API number identifies the wellbore, while the UIC number tracks the injection permit.
Do I need a wellbore sketch with the form?
Yes, if you answer “Yes” to Item 25 (multiple completion) or Item 26 (downhole water separation), the form’s note requires a wellbore sketch.
Can I file the H-1/H-1A package through the RRC Online System?
No. The injection and disposal permit package is filed on paper to the Environmental Services section in Austin, though you submit the well log online.
Do I still report to the Commission after the permit issues?
Yes. You must monitor injection pressure and volume at least monthly and report the results each year on Form H-10.
Related reading
- How to Fill Out Texas Railroad Commission Form H-1 (w/Examples) + FAQs
- How to Fill Out Texas Railroad Commission Form H-10 (w/Examples) + FAQs
- How to Fill Out Texas Railroad Commission Form H-5 (w/Examples) + FAQs
- How to Fill Out Texas Railroad Commission Form H-9 (w/Examples) + FAQs
- How to Fill Out Texas Railroad Commission Form W-14 (w/Examples) + FAQs
- How to Fill Out Texas Railroad Commission Form W-1X (w/Examples) + FAQs
- How to Fill Out Texas Railroad Commission Form W-10 (w/Examples) + FAQs