Texas Railroad Commission Form G-5, the Gas Well Classification Report, is the form an oil and gas operator files to prove a newly completed or reclassified well qualifies as a gas well under Texas rules. You file it in duplicate with the Railroad Commission of Texas (RRC) District Office after you complete a gas well, when you reclassify a well from oil to gas, or when the agency asks for it.
The form carries one revision date, Rev. 01/01/86, so check the top-left corner of your copy to confirm you have the right version before you write a single number on it. Filing it wrong is not a small problem: the RRC will not clear a single barrel of condensate from a gas well, and will not assign an allowable, until your G-5 is properly prepared, signed, and filed along with a Form P-4 naming the gatherer and a Form P-8 clearance request. Texas regulates more than 180,000 active gas wells, and each one needed a G-5 classification on file before it could legally sell its first cubic foot of gas.
This guide walks you through every line on the form with named examples, real fact patterns, and the exact consequences of common errors.
Here is what you will learn:
- 📋 What Form G-5 is, who must file it, and the four events that trigger a filing.
- 🧾 Every document, test result, and ID number you need to gather before you start.
- ✍️ A line-by-line walkthrough of all 14 numbered boxes and lettered test fields A through N.
- 🧪 When the ASTM distillation test is required and how to read the 100,000 CF/barrel rule.
- 🚫 The mistakes that get a G-5 rejected and freeze your condensate clearance.
What Form G-5 Is and Who Must File It
Form G-5 is the official report that tells the Railroad Commission of Texas how a well should be classified for regulatory purposes. The RRC is the state agency that regulates oil and gas in Texas, and it must know whether a well is an oil well or a gas well because each class follows different allowable, reporting, and clearance rules. The form is required under Statewide Rule 53, the rule that governs gas well classification. Without an accepted G-5, a gas well sits in limbo and cannot move its condensate to market.
The filer is the well operator, the person or company shown on the Form P-5 Organization Report as responsible for the well. In practice a petroleum engineer, a regulatory analyst, or a third-party consultant prepares the technical data, but the operator’s authorized agent signs it. Both large producers and small independent operators file the same form, and the standard is the same for each.
You must file Form G-5 in four situations, spelled out in the official instructions:
- a. Upon completion of a gas well.
- b. Upon reclassification of any well from oil to gas.
- c. Upon reclassification from gas to oil if the gas-oil ratio is more than 12,500 cubic feet per barrel and the oil gravity is more than 50 degrees API.
- d. Upon any later request by the Railroad Commission.
The consequence of ignoring a trigger is direct. If you complete a gas well and never file the G-5, the RRC will not assign an allowable, and any condensate you move is unauthorized production that can draw enforcement and severance-tax problems. A common misconception is that the Form G-1 completion report covers classification on its own. It does not. The RRC filing checklist shows the G-5 and back-pressure curve attach to the G-1, but the G-5 is its own required document with its own data.
Before You Start: Documents and Information You Need
Gathering your data first saves you from a half-finished form and a second trip to the District Office. The G-5 is short, but every number on it must come from a real test or an official record, not memory. Pull these items together before you open the form.
- Your Form P-5 operator name. Box 1 must match your Organization Report word for word; a mismatch makes the RRC unable to tie the well to your active P-5, and the form bounces.
- The well’s API number. The 14-digit API number (Box 6) is the well’s permanent fingerprint; without it the agency cannot match the report to the right wellbore.
- The RRC District number. Box 3 routes the form to the correct District Office; the wrong district sends it to the wrong reviewer and delays clearance.
- The Oil Lease No. or Gas Well ID No. Box 4 links the report to the lease or gas well identity already on file.
- The lease name, county, and survey location. Boxes 7, 9, and 10 place the well on the map; vague entries slow the cross-check against your drilling permit.
- The 24-hour production test results. Gas volume, oil/condensate volume, water volume, pressures, and choke size all flow from a stabilized or sales-line test taken on a 24-hour basis.
- The gas/liquid hydrocarbon ratio. This single number (Field E) decides whether you owe an ASTM distillation test, so calculate it before anything else.
- The liquid hydrocarbon sample and lab results. If the ratio is under 100,000 CF/barrel, you need a fresh stock-tank or flashed separator sample and a full ASTM distillation report.
- The gas specific gravity. Field N reports the gravity of the gas with air equal to 1.
- The pipeline connection or gas use. Box 11 states where the gas goes; a blank here raises a question about disposition.
If any item is missing, the form is incomplete and the District Office can return it, which restarts your clearance clock. A misconception worth killing early: operators think they can estimate the test numbers and “fix them later.” The signed declaration under Section 91.143 of the Texas Natural Resources Code makes false data a legal exposure, not a clerical edit.
Where to Get the Form and How to Access It
The official Form G-5 lives on the RRC Oil & Gas Forms page, which lists G-5 with a print PDF, a fillable PDF, and a Word version. Use the fillable PDF if you want to type your entries on a computer; use the print PDF if you prefer to complete it by hand in black ink. The same row links the back-of-form instructions PDF, which you should read before filling in any field.
To open the fillable version, you need Adobe Reader 6.0 or higher installed, per the RRC fill-in forms guidance. Download the file to your computer first, then open it in Reader rather than inside a browser tab, because some browsers will not save your typed data. Save a copy under the well’s API number so you can find it later.
The form is one page with the report on the front and the instructions on the back. Print two copies, because the instruction line requires you to file the report in duplicate. Keep a third copy for your own records as proof of what you submitted and when.
Step-by-Step: How to Fill Out Form G-5 Line by Line
The form has 14 numbered boxes for well identity plus a lettered test block (A through N) for the production and laboratory data. Complete the boxes top to bottom, then the test block, then the distillation table if required, then the signature. Use the exact field names printed on the form.
Box 1 — Operator Name (Exactly as shown on Form P-5 Organization Report)
This box asks for the legal name of the company or person who operates the well. Enter the operator name letter for letter as it appears on your active Form P-5, including punctuation, “LLC,” “Inc.,” or “Operating.” Write it in capital letters to match agency records. For example, PERMIAN BASIN OPERATING LLC writes its name exactly that way, not “Permian Basin Op.” or “PBO LLC.” The nuance: if your company recently changed its name or P-5 number, use the name on the current P-5, not an old letterhead. The most common mistake is shortening or abbreviating the name, which breaks the automatic match to your P-5 and gets the form held. A misconception is that any recognizable version of the name works; the RRC matches on an exact string, so close is not good enough.
Box 2 — Mailing Address
This box asks where the RRC should send correspondence about the well. Enter the operator’s full mailing address, including street or P.O. Box, city, state, and ZIP code, in standard format. For example, Permian Basin Operating LLC enters P.O. Box 4410, Midland, TX 79704. Use the same address tied to your P-5 so notices reach the right desk. A P.O. Box is fine here, because this is a mailing address and not the well location. The common mistake is entering the field office address instead of the company address of record, which sends RRC letters to the wrong place and means you miss a deficiency notice. People wrongly assume this address is the well site; the well’s physical location goes in Boxes 7 and 10, not here.
Box 3 — RRC District No.
This box asks which of the RRC’s regulatory districts the well sits in. Enter the district number that covers the county of the well site, such as 08 for much of the Permian Basin or 03 for the upper Gulf Coast. The district controls which District Office receives and reviews your form. For example, a well in Reeves County goes to District 08. Confirm the district on your drilling permit (Form W-1) rather than guessing. The common mistake is copying the district from a nearby lease in a different county, which routes the form to the wrong office and delays the entire clearance. A misconception is that the district is the same as the county; districts group many counties together, so look it up.
Box 4 — Oil Lease No. or Gas Well ID No.
This box asks for the existing identifier the RRC already assigned to the lease or the gas well. Enter the oil lease number if you are reclassifying from oil, or the gas well ID number for a gas completion. For example, on an oil-to-gas reclassification the operator enters the old oil lease number 12345. The nuance: a brand-new gas completion may not yet have a permanent gas ID, in which case you tie the report to the drilling permit and the District Office assigns the ID. The common mistake is leaving this blank on a reclassification, which leaves the agency unable to find the prior record. People wrongly think a new gas well always has its gas ID at completion; sometimes classification is what creates that record.
Box 5 — Well No.
This box asks for the specific well number within the lease or unit. Enter the well number exactly as it appears on your permit and completion paperwork, such as 1H or 3. This separates one wellbore from the others on the same lease. For example, State University 36 Well No. 2H enters 2H in this box. Match the suffix style, because a horizontal well’s “H” is part of its identity. The common mistake is entering a pad or pumping unit number instead of the permitted well number, which mismatches the report to the wellbore. A misconception is that the well number and API number are interchangeable; the well number is the operator’s label, while the API is the state’s permanent code.
Box 6 — API No. (42-)
This box asks for the well’s American Petroleum Institute number, the permanent code for every well in Texas. The form pre-prints 42- because 42 is the Texas state code, so you enter the remaining digits in the form county-unique number, for example 42-389-31415. This number never changes for the life of the wellbore. For instance, a Reeves County well enters 42-389- followed by its unique five-digit well number. The nuance: re-entries and recompletions keep the original API, so do not create a new one. The common mistake is transposing digits, which points the report at a different well and corrupts the public record. People wrongly believe a recompletion gets a fresh API; it keeps the original.
Box 7 — County of Well Site
This box asks for the Texas county where the well is physically located. Enter the full county name, such as Reeves or Karnes, with no abbreviation. The county must agree with the district in Box 3 and the survey in Box 10. For example, Reeves pairs with District 08. The nuance: if a lease straddles two counties, report the county where the wellbore is actually drilled. The common mistake is naming the county where the operator’s office sits instead of the well, which breaks the location chain. A misconception is that county and district are the same field; they are separate checks the RRC reconciles against each other.
Box 9 — Lease Name
This box asks for the name of the lease on which the well is completed. Enter the lease name exactly as it appears on the drilling permit and prior filings, such as Smith Ranch or State University 36. The lease name links the well to leasehold and unit records. For example, State University 36 goes in this box for a well on that lease. The nuance: pooled units may carry a unit name that differs from the original lease, so use the name the RRC already has on file. The common mistake is inventing a marketing name that does not match the permit, which fails the cross-check. People wrongly assume the lease name is informal; it is a matched field tied to the permit.
Box 10 — Location (Section, Block and Survey)
This box asks for the well’s legal land description. Enter the section, block, and survey (and abstract if used), such as Sec. 12, Blk. C-5, PSL Survey. This is how Texas pins a well to a precise spot on a land grid. For example, Sec. 36, Blk. 30, T-1-S, T&P RR Co. Survey. The nuance: West Texas uses block-and-section grids while other regions use abstracts and original grantees, so copy the format from your permit. The common mistake is rounding or paraphrasing the survey, which makes the location unverifiable. A misconception is that GPS coordinates replace the legal description; the RRC still wants the section-block-survey here.
Box 11 — Pipeline Connection or Use of Gas
This box asks where the gas goes after it leaves the well. Enter the name of the connecting pipeline or gas gatherer, or state the on-lease use such as lease fuel or gas lift. For example, Lone Star Gathering, Permian System names the connecting line. The nuance: if the well is not yet connected to a sales line, say so, because the instructions then require your production test to be at a stabilized rate rather than at sales-line conditions. The common mistake is leaving this blank, which raises a disposition question and stalls clearance. People wrongly think this box is optional for a new well; the RRC needs to know how the gas and condensate will move before it clears anything.
Production Test Block: Fields A through N
The lettered block reports a single 24-hour production test plus the related pressures and fluid properties. The instructions require the data to reflect representative operating conditions if the well is on a sales line, or a stabilized rate if it is not, and all volumes must be on a 24-hour basis. Enter each value in the unit printed beside it.
Field A — Date of Test
This field asks the date you ran the production test. Enter the date in month-day-year form, such as 03/14/2026. The date proves the test is recent and tied to the completion. For example, Permian Basin Operating LLC enters 03/14/2026. The nuance: the date should be close to the completion date on the Form G-1, because a stale test invites a question. The common mistake is entering the lab report date instead of the field test date, which mismatches the test sequence. People wrongly assume any recent date works; the RRC reads it against the completion and sample dates.
Field B — Gas Volume (Mcf)
This field asks the 24-hour gas production volume in thousand cubic feet. Enter the measured gas rate, such as 4,250 Mcf per day. This number anchors the gas/liquid ratio in Field E. For example, a well flowing 4.25 MMcf/day enters 4,250. The nuance: report the volume at the elected test rate on a full 24-hour basis even if you tested for fewer hours, by scaling to 24 hours. The common mistake is reporting raw test-period volume rather than the 24-hour figure, which throws off the ratio and the classification. A misconception is that any flow rate proves a gas well; classification depends on the ratio, not the gas volume alone.
Field C — Oil or Condensate Volume (Bbl)
This field asks the 24-hour liquid hydrocarbon volume in barrels, with separate spots for Separator and Stock Tank. Enter the condensate measured during the same test, such as 35 barrels. For example, 35 Bbl stock-tank condensate. The nuance: report where the liquid was measured, because separator and stock-tank volumes differ after the liquid flashes to atmospheric pressure. The common mistake is mixing produced water into the condensate figure, which inflates the liquid and distorts the ratio. People wrongly call all produced liquid “oil”; on a gas well the hydrocarbon liquid is condensate, and water is reported separately.
Field D — Water Volume (Bbl)
This field asks the 24-hour produced water volume in barrels. Enter the water measured during the test, such as 12 barrels. For example, 12 Bbl. The nuance: water is kept out of the hydrocarbon ratio, so reporting it here keeps Field E clean. The common mistake is lumping water with condensate, which wrongly lowers the gas/liquid ratio and can force an unnecessary distillation test. A misconception is that water volume is unimportant; it confirms the liquids are split correctly.
Field E — Gas/Liquid Hydrocarbon Ratio (Cf/Bbl)
This field asks the ratio of gas to liquid hydrocarbon, the number that decides the whole classification. Divide the 24-hour gas volume in cubic feet by the barrels of condensate. For example, 4,250 Mcf is 4,250,000 cubic feet; divided by 35 barrels that is 121,429 CF/Bbl. The nuance and the heart of the form: if this ratio is less than 100,000 CF/barrel, you must run the ASTM distillation test; if it is 100,000 or higher, you skip it. The common mistake is using Mcf instead of cubic feet in the math, which understates the ratio by a factor of 1,000 and triggers a test you do not owe. People wrongly think a high gas volume alone clears the test requirement; only the ratio does.
Fields F, G, and H — Flowing Tubing Pressure, Choke Size, Casing Pressure
These three fields ask the pressures and choke used during the test. Enter flowing tubing pressure in psia (Field F), choke size in inches (Field G), and casing pressure in psia (Field H), such as 1,150 psia, 24/64 in., and 900 psia. For example, a well tested on a 24/64 choke. The nuance: the choke and pressures must match the elected test rate, because they document how the rate was achieved. The common mistake is leaving choke size blank, which leaves the RRC unable to judge whether the test rate is representative. A misconception is that pressures are optional engineering detail; they are part of how the agency validates the test.
Field J — Separator Operating Pressure (psia)
This field asks the pressure at which the separator ran during sampling. Enter the value in psia, such as 400 psia. For example, 400 psia. The nuance: separator pressure matters because the liquid sample must later be flashed to atmospheric pressure before the API gravity or distillation test, per the instructions. The common mistake is reporting line pressure instead of separator pressure, which misstates the sampling conditions. People wrongly skip this on a stock-tank sample; report it whenever a separator is in the test stream.
Field K — Color of Stock Tank Liquid
This field asks the visible color of the stock-tank liquid. Enter a short description, such as straw or water-white. For example, straw-colored. The nuance: condensate is usually light or clear, so a dark color may suggest the liquid is closer to crude oil and supports a different classification. The common mistake is leaving it blank because it seems trivial; color is a quick sanity check on the liquid type. A misconception is that color does not matter; it is a recognized field clue about whether the well is truly a gas well.
Fields L and M — Gravity of Separator Liquid and Stock Tank Liquid (API)
These fields ask the API gravity of the separator liquid (Field L) and the stock-tank liquid (Field M). Enter each in degrees API, such as 58.0 API stock tank. For example, 58.0 API. The nuance: the sample must be flashed to atmospheric pressure and stabilized at 60 degrees Fahrenheit before you measure gravity, or the reading is wrong. The common mistake is reporting pressurized-sample gravity, which reads artificially high. People wrongly think one gravity reading covers both; the form wants separator and stock-tank gravities reported separately.
Field N — Specific Gravity of the Gas (Air = 1)
This field asks the specific gravity of the produced gas relative to air. Enter the value with air equal to 1, such as 0.65. For example, 0.65 (Air = 1). The nuance: this comes from a gas analysis, so use the lab number rather than a guess. The common mistake is entering the liquid gravity here by accident, which is nonsensical for a gas reading. A misconception is that gas gravity is optional; it characterizes the produced gas and belongs on every G-5.
ASTM Distillation of Liquid Sample (Required Only If Ratio Is Under 100,000 CF/Bbl)
This table asks for the lab distillation profile of the liquid hydrocarbon sample, and you complete it only if Field E is below 100,000 CF/barrel. Enter the Initial Boiling Point, then the temperature in degrees Fahrenheit at which 10, 20, 30, 40, 50, 60, 70, 80, 90, and 95 percent have distilled over, plus the End Point, Total Recovery, Residue percent, and Loss percent. For example, a lab reports an Initial Boiling Point of 96°F, 10% over at 150°F, on up to a 95% point of 430°F, with Residue 1.2% and Loss 0.8%. The nuance: the sample must be a fresh stock-tank liquid or a separator sample flashed to atmospheric pressure and stabilized at 60°F before the test begins. The common mistake is filling this table when the ratio is above 100,000 CF/barrel, which wastes lab money and clutters the form; the opposite mistake, skipping it when the ratio is under 100,000, gets the form rejected as incomplete. A misconception is that the operator can eyeball these numbers; they must come from a real ASTM distillation run by a lab.
Shut-in Wellhead Pressure (psia)
This field asks the well’s shut-in wellhead pressure. Enter the stabilized shut-in pressure in psia, such as 3,200 psia. For example, 3,200 psia. The nuance: this reading should be taken after the well has stabilized while shut in, not immediately after closing the valve. The common mistake is reporting a pressure that has not stabilized, which understates reservoir energy. People wrongly think flowing pressure can stand in for shut-in; they are different readings.
Signature Block — Name, Title, Signature, and the Section 91.143 Declaration
This block asks the authorized agent to certify the report under penalty of law. Type or print the preparer’s name, enter the title, and sign, certifying under Section 91.143, Texas Natural Resources Code that the data are true, correct, and complete. For example, James Okafor, Regulatory Manager signs and prints his name and title. The nuance: only a person authorized under the operator’s P-5 should sign, because the signature binds the operator. The common mistake is filing an unsigned form, which is void on arrival. A misconception is that the declaration is boilerplate; it makes false statements a legal violation, not a typo.
Three Filled-Out Examples Using Real Scenarios
These three fact patterns show the most common ways operators complete the G-5. Each follows one named filer through the form.
Scenario 1 — James Okafor files for a newly completed dry gas well above the 100,000 ratio.
| Form Section | What James Enters |
|---|---|
| Box 1 Operator Name | PERMIAN BASIN OPERATING LLC |
| Box 3 RRC District No. | 08 |
| Box 6 API No. | 42-389-31415 |
| Box 9 Lease Name | State University 36 |
| Box 11 Pipeline Connection | Lone Star Gathering, Permian System |
| Field B Gas Volume | 4,250 Mcf |
| Field C Oil/Condensate Volume | 35 Bbl (stock tank) |
| Field E Gas/Liquid Ratio | 121,429 CF/Bbl |
| ASTM Distillation Table | Left blank — ratio over 100,000 |
| Signature | James Okafor, Regulatory Manager |
Scenario 2 — Maria Delgado files for a gas-condensate well below the 100,000 ratio.
| Form Section | What Maria Enters |
|---|---|
| Box 1 Operator Name | DELGADO ENERGY INC |
| Box 7 County of Well Site | Karnes |
| Box 6 API No. | 42-255-20817 |
| Field A Date of Test | 03/14/2026 |
| Field B Gas Volume | 3,000 Mcf |
| Field C Condensate Volume | 45 Bbl (stock tank) |
| Field E Gas/Liquid Ratio | 66,667 CF/Bbl |
| Field M Gravity of Stock Tank Liquid | 56.0 API |
| ASTM Distillation Table | IBP 96°F; 50% at 280°F; End Point 430°F; Residue 1.2%; Loss 0.8% |
| Signature | Maria Delgado, President |
Scenario 3 — Robert Lin reclassifies a well from oil to gas.
| Form Section | What Robert Enters |
|---|---|
| Box 1 Operator Name | LIN PETROLEUM OPERATING LLC |
| Box 4 Oil Lease No. | 12345 (existing oil lease) |
| Box 5 Well No. | 2H |
| Box 6 API No. | 42-371-44102 |
| Field B Gas Volume | 2,800 Mcf |
| Field C Condensate Volume | 18 Bbl |
| Field E Gas/Liquid Ratio | 155,556 CF/Bbl |
| ASTM Distillation Table | Left blank — ratio over 100,000 |
| Box 11 Pipeline Connection | Eagle Ford Gathering Co. |
| Signature | Robert Lin, Operations Engineer |
How to File the Completed Form
You file Form G-5 in duplicate with the appropriate Railroad Commission District Office, per the back-of-form instructions. For a new gas well, the form attaches to your Form G-1 completion package along with the back-pressure curve, so file them together. There is no filing fee for the G-5 itself.
Filing channels and details:
- In person or by mail to the District Office. Bring or mail two signed copies to the District Office that covers the well’s county; the office stamps and routes them. Keep your third stamped copy as proof of filing.
- As part of the central completion filing. New-well completion data is processed through the RRC Online System and the Austin records unit; the filing checklist shows where the G-5 and curve attach to the G-1.
- Companion forms for clearance. Before any condensate moves, also file a Form P-4 naming the gatherer and a Form P-8 request for clearance stating the amount of condensate to be moved.
Accepted submission methods at the District Office are mail and in-person delivery; some districts accept fax or email for supporting copies, so call your district to confirm. Expected processing depends on workload, so file well before you need the allowable. Always keep a date-stamped copy, because that stamp is your proof of timely filing if a question comes up later.
What Happens After You File
After the District Office receives a complete, signed G-5, it reviews the test data and the ratio to confirm the well meets the gas-well standard under Statewide Rule 53. If the ratio and supporting data check out, the well is classified as a gas well and becomes eligible for an allowable. Only then will the RRC clear condensate, and only after the matching Form P-4 and Form P-8 are on file.
If the form is incomplete, unsigned, or shows data that conflicts with the G-1 or permit, the office returns it or asks for more information, which pauses the clearance. The notice goes to the mailing address in Box 2, which is why that address must be current. A missed notice means a longer delay.
Once classified, the well’s data becomes part of the public record searchable through the RRC well records system. Title researchers and other operators often pull the G-5 to read the initial 24-hour test volumes, so accuracy here follows the well for its entire life.
Mistakes to Avoid When Filling Out the Form
- Abbreviating the operator name in Box 1. The form will not match your P-5 and gets held.
- Transposing digits in the API number. The report points at the wrong wellbore and corrupts the record.
- Using Mcf instead of cubic feet in the Field E ratio. The ratio drops by 1,000x and triggers an unneeded distillation test.
- Lumping water into the condensate volume. It distorts the ratio and can force a test you do not owe.
- Skipping the ASTM table when the ratio is under 100,000. The form is rejected as incomplete.
- Filling the ASTM table when the ratio is over 100,000. You waste lab cost and clutter the form.
- Reporting test-period volume instead of the 24-hour figure. The classification math comes out wrong.
- Measuring gravity on a pressurized sample. The API reading reads too high and misstates the liquid.
- Leaving Box 11 blank. The RRC cannot confirm gas disposition and stalls clearance.
- Filing only one copy. The instructions require duplicate copies, so a single copy is non-compliant.
- Filing the G-5 without the P-4 and P-8. No condensate will be cleared even if the G-5 is perfect.
- Sending the form to the wrong District Office. The form sits unreviewed while your allowable waits.
Do’s and Don’ts
Do:
- Do copy the operator name from your current P-5, because the RRC matches it as an exact string.
- Do calculate the Field E ratio in cubic feet first, because it decides whether you owe a distillation test.
- Do flash and stabilize the liquid sample before testing, because pressurized samples give false gravities.
- Do file in duplicate, because the instructions require two copies.
- Do file the P-4 and P-8 alongside the G-5, because condensate cannot clear without them.
- Do keep a date-stamped copy, because it is your only proof of timely filing.
Don’t:
- Don’t guess the test numbers, because the Section 91.143 declaration makes false data a legal risk.
- Don’t mix water with condensate, because it warps the classification ratio.
- Don’t abbreviate the lease or survey, because the cross-check against your permit will fail.
- Don’t sign without authority, because only a P-5 agent can bind the operator.
- Don’t reuse an old API on a recompletion’s “new” well, because each wellbore keeps its own permanent API.
- Don’t file the form unsigned, because an unsigned G-5 is void.
Pros and Cons of Filing on Your Own vs. With Help
| Filing It Yourself | Using an Engineer or Consultant |
|---|---|
| Pro: No consultant fee, which saves money on a simple high-ratio well. | Pro: A petroleum engineer reads the test data correctly, which avoids ratio errors. |
| Pro: You control the timing and can file the moment the test is back. | Pro: A consultant knows when the ASTM test is truly required, which prevents wasted lab cost. |
| Pro: You learn your own well data, which helps with future filings. | Pro: Experienced filers match P-5 and permit data exactly, which avoids holds. |
| Pro: Good fit for a single, clearly classified gas well. | Pro: They coordinate the G-5, G-1, P-4, and P-8 as one package, which speeds clearance. |
| Con: Easy to miss the cubic-feet ratio math, which triggers rejection. | Con: Professional fees add cost to every well. |
| Con: You may not know the duplicate-copy and companion-form rules. | Con: You depend on their schedule, which can slow filing. |
| Con: A wrong entry follows the well permanently in public records. | Con: You still must supply accurate field data, so oversight is still on you. |
FAQs
Do I have to file a G-5 for every gas well?
Yes. You file it on completion of a gas well, on reclassification from oil to gas, on certain gas-to-oil reclassifications, and whenever the Railroad Commission requests it.
Is there a filing fee for Form G-5?
No. The G-5 itself carries no filing fee, though related tests and lab work cost money and other forms in the package may have their own requirements.
Do I always need the ASTM distillation test?
No. You run it only when the gas/liquid hydrocarbon ratio in Field E is less than 100,000 cubic feet per barrel; at or above that, you skip it.
Do I write the operator name in Box 1 the way my logo shows it?
No. You enter it exactly as it appears on your current Form P-5 Organization Report, with no abbreviations, or the form fails the match.
Do I put the well’s physical address in Box 2?
No. Box 2 is the operator’s mailing address; the well’s location goes in Box 7 (county) and Box 10 (section, block, and survey).
Do I report gas volume in Mcf or cubic feet in Field E?
Yes, convert to cubic feet for the ratio; Field B is in Mcf, but the Field E ratio is cubic feet per barrel, so multiply Mcf by 1,000 first.
Do I include produced water in the condensate volume?
No. Water goes in Field D and condensate goes in Field C, because mixing them distorts the classification ratio.
Do I keep the same API number after a recompletion?
Yes. The API number in Box 6 stays with the wellbore for its life, so never create a new one for a recompletion.
Do I need to file more than one copy?
Yes. The instructions require you to file the report in duplicate at the appropriate District Office, plus keep a copy for yourself.
Do I have to file the P-4 and P-8 with the G-5?
Yes, before any condensate moves; no condensate clears from a gas well until the G-5, a P-4 naming the gatherer, and a P-8 clearance request are all on file.
Do I measure liquid gravity straight from a pressurized separator sample?
No. Flash the sample to atmospheric pressure and stabilize it at 60 degrees Fahrenheit first, or the API gravity reading will be wrong.
Do I have to read the back of the form?
Yes. The back holds the filing rules, the production-test conditions, and the Statewide Rule 53 reference you need to complete the form correctly.
Do I sign the G-5 myself if I am not the owner?
Yes, if you are authorized under the operator’s P-5; the signature certifies the data under Section 91.143 of the Texas Natural Resources Code.
Do I use the lab report date or the field test date in Field A?
No to the lab date; enter the date you ran the production test in the field, because the RRC reads it against the completion and sample dates.
Related reading
- How to Fill Out Texas Railroad Commission Form G-1 (w/Examples) + FAQs
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